4 - 2017 - Canadian Energy News, Top Headlines, Commentaries, Features & Events

B.C. Liberals to repeal Vancouver natural gas ban that city says doesn’t exist

April 29, 2017 by The Canadian Press

VANCOUVER — The B.C. Liberals say they will repeal a City of Vancouver plan the party claims prohibits natural gas in some new buildings, but the city says no such ban exists.

Andrew Wilkinson, candidate for Vancouver-Quilchena, said on Saturday the city’s ban would increase costs to consumers, businesses and residents because it would raise building costs and create a reliance on electricity, which is more expensive.

In a statement responding to the announcement, the city said it has no plans for an outright ban on the use of natural gas.

The city does have a new building policy, which goes into effect Monday, that sets energy efficiency and emissions targets for new construction on rezoned lots.

“Developers can choose to build new buildings with natural gas, provided they can meet the energy efficiency and emissions targets,” the statement said, adding the targets require a 50 per cent decrease in greenhouse gas emissions.

Documents from a city presentation on Friday explain that the regulation will typically apply to taller residential or commercial buildings, which account for about 55 per cent of new development.

Wilkinson said if the Liberals form the government after the May 9 election, they’ll change the Vancouver Charter that allows the city to dictate its own building codes in order to repeal restrictions on natural gas.

“It’s essential that Vancouverites be able to keep their costs down. We do not support processes and programs that drive up costs,” he said.

Coun. Andrea Reimer said she’s perplexed by Wilkinson’s statements, which do not represent the facts of the city’s plan.

“It’s definitely a concern when a candidate in an election campaign is using inaccurate information,” she said. “There is no ban, ergo legislation to stop a ban would functionally have no impact.”

She said the city is moving to reduce emissions and encourage the use of renewable resources over the 35 years, but there is no intention to ban natural gas.

A statement the city issued in February said natural gas would still be allowed in new buildings under six storeys for use in fireplaces, cooking ranges, furnaces, domestic hot water and laundry dryers.

These changes have been in the works since November 2015 when the city approved its strategy to achieve 100 per cent renewable energy use by 2050.

Wilkinson said the Liberals waited until now to take a stance on the issue because changes to the city’s building code go into effect Monday.

“It’s timely to get out the word now so people don’t make decisions and face a flip-flop in the city of Vancouver. We want the status quo to continue,” he said.

But Reimer said the city’s new building regulation, which was approved in November 2016, aligns with the province’s recent B.C. Energy Step Code that requires improved energy efficiency for buildings.

“It does exactly the same thing as the policies we’d be bringing in, although our policy applies to much fewer buildings than the Step Code applies to,” she said.

The city’s statement said its move to reduce greenhouse gas emissions is necessary in order to combat climate change, while supporting the “green building sector” and making energy costs more affordable.

“The province states that the Vancouver region will need to invest over $10 billion in preparing and adapting to climate change due to sea level rise and increased storms and droughts. Only by reducing greenhouse gases today can we ensure this number does not increase,” said a statement from the city.

—Follow @Givetash on Twitter.

Linda Givetash, The Canadian Press

Forums & Conferences: See Them HERE & REGISTER – Global Petroleum Show 2017

June 28, 2017April 28, 2017 by EnergyNow Media

Global Petroleum Show unites energy leaders and industry professionals, allowing you to learn from high-level representatives, decision makers and experts. Indigenous Conference on Energy and Mining Join us for this insightful, one of a kind forum focused on understanding and sharing important issues to indigenous people. Indigenous leaders, leaders from energy companies, foreign and domestic … Read more

2024 National Coalition of Chiefs Energy And Natural Resource Summit

Quantum Downhole Systems: Making Wells Great Again – Using Data-Driven Technology to Add Greater Value

June 28, 2017April 28, 2017 by EnergyNow Media

“Canada is one of the best places in the world where great technology is developed,” says Steven Winkler, President and Director of Quantum Downhole Systems (‘Quantum’). And Quantum is leading the way in developing some of Canada’s innovative technology within the oil and gas industry, specifically with their wellbore milling, cleaning and production evaluation technology. … Read more

‘Our hearts were broken:’ Family mourns son killed in workplace accident

May 1, 2017April 28, 2017 by The Canadian Press

CALGARY — The grieving father of a young man who died in a workplace accident in Alberta’s oilsands region interrupted a courtroom apology Friday from one of the owners of a company that pleaded guilty in the death.

Jordan Gahan, who was 21 and from Fredericton, was operating heavy equipment at a Suncor pit that was being reclaimed near Fort McMurray when his excavator fell through ice into four metres of water. His co-workers were able to get him to the surface, but he died in hospital.

Brayford Trucking Ltd. pleaded guilty to two of five charges under Alberta’s Occupational Health and Safety Act for failing to protect Gahan as an employee.

“There’s no words or actions or anything that can possibly express to you how sorry we are and you no longer have your son. We can’t even begin to imagine the pain and suffering that’s associated with losing a child,” co-owner Susan Brayford said in a statement to the court Friday.

“We’re so very, very sorry.”

Brayford was interrupted by Paul Gahan.

“I apologize to the court, but it’s just too much,” he yelled.

Judge Harry Van Harten allowed Gahan to address the court, but with a warning.

“I totally appreciate how difficult a day this is for you, but it is for everyone that’s here,” he said. “I’m happy to hear what you have to say. Just do it in a respectful way please.”

Gahan said he appreciated that the Brayfords had “stepped up to the plate” and changed their safety policies.

“It’s sad that it has to come at the cost of my dear son. On March 14, 2014, I was sentenced to … basically life in prison with no chance of parole until I die. I was sentenced by the incompetence and the capabilities that didn’t follow procedures properly,” Gahan said.

Six pictures of his son were placed in the courtroom to give the family comfort. Leica Gahan, Jordan’s mother, said she didn’t want to believe the RCMP when they told her that he had died.

“I begged and pleaded with the RCMP that they had made a mistake. They made no mistake. Our son was gone and our hearts were broken,” she said.

“I know that grieving for Jordan will last a lifetime. I will grieve for him until the day we are reunited in heaven. Losing my son Jordan was the worst thing that could ever happen to me in my 50 years on this earth.”

The court imposed a fine of $100,000 as well as two years of corporate probation under the Criminal Code.

“It was a meaningless and preventable death,” said Van Harten.

But there are mitigating factors, including changes to safety measures at the company and the plea of guilty, he added.

Van Harten also noted there was also a personal apology and expression of sorrow from the Brayfords, whom he described as “conscientious contributing citizens of the community.”

“The Brayfords are clearly not hiding behind the corporate shield as they might legally be allowed to do. Unlike some corporations … this company is not going to pay a penalty and move on and consider the penalty the simple cost of doing business.”

— Follow @BillGraveland on Twitter

Bill Graveland, The Canadian Press

Federal energy regulator says she won’t seek new term

April 28, 2017 by The Canadian Press

WASHINGTON — One of two remaining members of the Federal Energy Regulatory Commission says she will not seek a second term, a move that could leave the five-member panel with a single commissioner.

Democrat Colette Honorable said Friday she will not seek appointment after her current term expires in June. Honorable has served on the energy panel since 2014.

President Donald Trump tapped Democrat Cheryl LaFleur to lead the commission but has yet to fill three Republican vacancies. The vacancies have left the agency without a quorum and prevent it from making high-profile decisions on interstate pipelines or proposed mergers.

Honourable did not say when she will step down. An agency spokeswoman says Honorable could stay on until a new commissioner arrives or until Congress adjourns next year.

Matthew Daly, The Associated Press

EXCaliber Series of Explosion-Proof Air-Sensing Thermostats Now Offered by Hazloc Heaters

June 28, 2017April 28, 2017 by EnergyNow Media

Calgary, Alberta: April 28, 2017 Hazloc Heaters™, a leading manufacturer of industrial heating products for hazardous and severe-duty locations, is pleased to announce the introduction of the EXCaliber Series of explosion-proof air-sensing thermostats certified to Canadian and American Division and Zone system standards (CCSAUS). The EXCaliber Series of thermostats are available in a Bi-metal (BTX) … Read more

PROPANE by Parkland Fuel Corporation: A story of growth in service, delivery & national supply

October 12, 2017April 28, 2017 by EnergyNow Media

When it came time for Parkland Fuel Corporation (Parkland, TSX: PKI) to add an alternative fuel to their multi-fuel product mix, propane became an obvious choice. As one of Canada’s best alternative fuel solutions that carries more energy density than natural gas, at a lower price and carbon cost than other conventional fuels, propane simply … Read more

Court agrees to hold off ruling on carbon restrictions

May 1, 2017April 28, 2017 by The Canadian Press

WASHINGTON — In a blow to environmental groups, a federal appeals court agreed on Friday to postpone a ruling on lawsuits that challenge Obama-era limits on carbon emissions.

The limits are part of the Clean Power Plan, a centerpiece of President Barack Obama’s efforts to reduce emissions from existing power plants. The Clean Power Plan was challenged by a coalition of states and industry groups that profit or benefit from the continued burning of coal, the dirtiest of fossil fuels.

The Environmental Protection Agency asked the U.S. Court of Appeals for the District of Columbia Circuit to put the legal fight on hold after President Donald Trump signed an executive order to roll back the plan. Trump has called climate change a hoax, disputing the overwhelming consensus of scientists that the world is warming and that man-made carbon emissions are primarily to blame.

Friday’s order from the court agreed to postpone the case for 60 days and asks the parties for guidance on whether the rule should be sent back to the EPA to potentially be revised or repealed.

While not final, the postponement is letdown to environmentalists who vehemently opposed the request for delay. They have urged the court to rule on the merits of the case, despite the change in administration.

“We are in a race against time to address the climate crisis,” said Vickie Patton, a lawyer for the Environmental Defence Fund. “Climate progress and clean energy cannot be stopped by the litigation tactics of polluters.”

The Supreme Court last year blocked the Clean Power Plan from taking effect while the appeals court considered whether it was legal. Ten judges on the court of appeals in Washington heard arguments in the case last year and could have issued a ruling at any time.

“Today’s decision by the court is a positive step toward protecting West Virginia coal miners and those who depend upon their success,” said West Virginia Attorney General Patrick Morrisey, who was among those who challenged the rules. “The court recognized the landscape has changed and that a decision on the merits is not appropriate at this time.”

The Clean Power Plan sought to reduce carbon emissions from existing power plants by about one-third by 2030, a goal in line with the United States’ commitment under the global climate treaty signed by nearly 200 countries in Paris in 2015. About two dozen mostly coal-friendly states and more than 100 companies sued to stop the Clean Power Plan, calling it an unconstitutional power grab. Opponents claim the plan will kill jobs, slash demand for coal and increase electricity prices.

Trump has pledged to reverse decades of decline in a U.S. coal industry under threat from such cleaner sources of energy as natural gas, wind turbines and solar farms. He has also said he plans to “renegotiate” the Paris accord.

In a second order issued Friday, the appeals court in Washington also postponed consideration of a separate case challenging an EPA rule capping greenhouse gas emissions from new or renovated power plants.

Under a prior Supreme Court ruling, EPA is required to regulate carbon emissions. But Trump’s appointees could seek to greatly dial back the level of reductions mandated under the Obama-era plan.

Jonathan Adler, a Case Western Reserve University law professor, said the order gives the Trump administration a chance to show it is moving forward with its own regulations to replace the current plan. He noted that the appeals court is requiring the EPA to submit status reports on its progress every 30 days.

“The court doesn’t want to rule on something that doesn’t have to be ruled upon,” Adler said. “At the same time, the court doesn’t want the let the agency shirk its obligations, either.”

___

Follow Associated Press environmental writer Michael Biesecker at www.Twitter.com/mbieseck

Michael Biesecker And Sam Hananel, The Associated Press

Rooster Energy Announces Fourth Quarter and Fiscal Year 2016 Financial, Operating and Reserve Report Results

April 28, 2017 by The Canadian Press

FOR: ROOSTER ENERGY LTD.
TSX VENTURE SYMBOL: COQ

Date issue: April 28, 2017
Time in: 7:15 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 28, 2017) – ROOSTER ENERGY LTD. (the
“Company”) (www.roosterenergyltd.com) (TSX VENTURE:COQ) is pleased to announce
it has filed on SEDAR (www.sedar.com) its Forms 51-101F1, 51-101F2 and 51-101F3
which includes summary data on the Company’s proved and probable reserves as of
December 31, 2016. Additionally, the Company has filed its audited financial
statements, related management discussion and analysis (“MD&A”) for the three
months (“Q4 2016”) and twelve months ended December 31, 2016 (“FY 2016”).
Selected financial and operational information for Q4 2016, FY 2016 is outlined
below and should be read in conjunction with the financial statements and
related MD&A. All dollar amounts herein are expressed in U.S. dollars.

HIGHLIGHTS:

/T/

— Q4 2016 EBITDA Totaled US$6.3 Million Driven By Well Services Activity
— FY 2016 EBITDA Totaled US$21.5 Million Compared To $24.1 Million In FY

2015
— Proved & Probable Reserves Total 12.1 MMBOE, NPV-10% US$126.9 Million

/T/

In Q4 2016, the Company produced 149,690 boe, compared to 205,010 boe produced
in Q4 2015, a 27% decrease. The lower sales volumes, combined with a
significant drop in the gain associated with the Company’s derivative
contracts, resulted in a 66% drop in Oil & Gas segment revenues in Q4 2016 to
$2.5 million. The decline in revenues was partially mitigated by a 35% drop in
lease operating expenses. The Oil & Gas segment reported EBITDA of $0.4 million
in Q4 2016 compared to a $0.8 million in Q4 2015, representing a 49% drop from
the prior year period.

Utilization at the Well Services segment averaged 19% in Q4 2016, compared to
30% in Q4 2015, a decline of 11 percentage points, as lower cash flows
continued to weigh on operator budgets and activity levels. As a result, Well
Services revenues declined 69% in Q4 2016 to $1.8 million. However, lower
revenues were largely offset by a 62% drop in operating expenses.
Decommissioning revenues fell 42% from the prior year period to $6.1 million,
due to reduced activity levels associated with the three Cochon fields. In
July, 2016, the Company announced that it had entered into a $22 million
decommissioning contract that was expected to be completed by the end of the
year; however, most of the work related to this contract was deferred to Q1
2017. The Well Services segment reported EBITDA of $6.7 million in Q4 2016
compared to $11.9 million in Q4 2015, which represents a 44% drop from the
prior year period.

In Q4 2016, the Company’s consolidated EBITDA totaled $6.3 million compared to
$11.4 million in Q4 2015, representing a 45% drop from the prior year period.
The Company recorded a net loss of $66.8 million in Q4 2016, which includes
$59.6 million of non-cash impairment and asset retirement expenses. Most of the
impairment charge relates to the write-off of the High Island A494 development,
as the Company’s inability to complete the #B-4 well resulted in the expiration
of the lease in January, 2017.

Rooster’s proved & probable reserves fell 28%, or 4.7 million barrels of oil
equivalent (MMBOE), to 12.1 MMBOE at December 31, 2016, primarily due to
negative revisions associated with the High Island A494, Vermilion 67, and
Eugene Island 44 fields. At December 31, 2016, the pre-tax NPV-10% value of
Rooster’s proved & probable reserves totaled $126.9 million. The Company’s
reserves were evaluated by Netherland, Sewell & Associates, Inc. (NSAI) in
accordance with Canadian National Instrument 51-101.

SUMMARY OF NI 51-101 RESERVE REPORT

/T/

Future Cash Flow (Pre-
Net Reserves Tax)
——————————— ———————-
Crude Natural
Oil Cond/NGLs Gas Total Undiscounted NPV-10%
MBbls MBbls MMcf MBoe ($000s) ($000s)
—– ——— ——– ——– ———— ———
Proved Developed
Producing 24.2 393.6 13,399.4 2,651.0 28,718.8 22,838.9
Proved Developed
Non-Producing 30.4 14.2 409.2 112.8 1,653.6 1,291.7
Proved Undeveloped 0.0 158.3 2,168.8 519.8 1,231.0 855.9
Total Proved 54.6 566.1 15,977.4 3,283.6 31,603.4 24,986.5

Probable 80.9 2,583.9 36,889.0 8,813.0 141,406.9 101,918.1
Total Proved +
Probable 135.5 3,150.0 52,866.4 12,096.6 173,010.3 126,904.6

/T/

As previously reported, in November, 2016, the Company received a notice of
default on its Senior Secured Notes for non-compliance with certain covenants
required by the Note Purchase Agreement, as amended. As a result, the Senior
Secured Notes were classified as current at December 31, 2016, which
contributed to a $69.0 million working capital deficit.

Kenneth F. Tamplain, Jr., interim Chief Executive Officer, commented that
“despite the difficult commodity price environment and subdued activity levels
in the Gulf of Mexico, the Company was able to generate $21.5 million of EBITDA
in FY 2016, largely driven by execution on its decommissioning contracts. In
the first four months of 2017, Well Services activity levels have improved from
prior year levels, and the Company has nearly completed its $22 million
decommissioning contract. However, the Company is currently operating without a
forbearance agreement with the holders of our Senior Secured Notes while
managing a significant working capital deficit. As such, until a restructuring
of the Senior Secured Notes is executed, the Company’s liquidity constraints
remain an immediate challenge for the Company.”

On March 24, 2017, the Company and holders of the Senior Secured Notes entered
into a non-binding term sheet setting forth the general terms of a potential
restructuring of the Note Purchase Agreement. The Company is and continues to
conduct business as usual and continues in negotiations with the holders of the
Senior Secured Notes to restructure the terms and conditions of the Note
Purchase Agreement and its obligations thereunder in accordance with the term
sheet. However, the holders of the Senior Secured Notes may exercise their
remedies against the Company at any time since there is no forbearance
agreement currently in place. In that event, or if the Company is ultimately
unable to finalize the documents to satisfactorily restructure the Senior
Secured Notes, then the Company would in all likelihood exercise all of its
available alternatives to preserve the going concern value of the Company. Such
alternatives could include filing a voluntary petition for relief under Chapter
11 of the U.S. Bankruptcy Code or similar restructuring laws, with recognition
of any orders entered thereunder in the appropriate jurisdiction in Canada.

SUMMARY OF OPERATING AND FINANCIAL RESULTS FOR Q4 2016 AND FY 2016

/T/

For the three months ended For the year ended
December 31, December 31,
—————————– —————————–
2016 2015 2016 2015
————– ————– ————– ————–
Oil & Gas Sale
Volumes
Crude oil (Bbls) 23,939 18,215 110,129 199,663
NGLs (Bbls) 11,234 29,658 77,756 72,505
Natural gas
(Mcf) 687,106 942,826 2,890,483 4,221,151
—————- ————– ————– ————– ————–
Total (BOE) (a) 149,690 205,010 669,633 975,693
Daily (BOE per
day) (a) 1,627 2,228 1,830 2,673

Financials
Revenues $ 10,282,144 $ 23,407,421 $ 33,325,288 $ 67,459,817
Operating
Expenses (65,155,957) (44,493,661) (89,622,079) (86,519,391)
—————- ————– ————– ————– ————–
Operating income
(loss) (54,873,813) (21,086,240) (56,296,791) (19,059,573)
Gain on asset
retirement
obligation (595,955) 1,029,255 4,690,995 4,815,928
Unrealized gain
(loss) on
financing
warrants – – – 1,000
Finance expenses
(b) (9,062,811) (3,313,868) (19,751,671) (12,746,628)
—————- ————– ————– ————– ————–
Income before
income taxes (64,532,580) (23,370,853) (71,357,468) (26,989,274)
Deferred income
tax expense
(recovery) 2,242,000 (8,486,000) (102,000) (7,804,000)
—————- ————– ————– ————– ————–
Net income
(loss) $ (66,774,580) $ (14,884,853) $ (71,255,468) $ (19,185,274)
—————- ————– ————– ————– ————–
—————- ————– ————– ————– ————–

Net income
(loss) per
share

Basic (0.21) (0.05) (0.22) (0.06)
Diluted (0.21) (0.05) (0.22) (0.06)

Weighted average
shares
outstanding

Basic 324,099,502 324,099,502 324,099,502 324,099,502
Diluted 324,099,502 324,099,502 324,099,502 324,099,502

EBITDAX (c)

Oil & Gas $ 418,094 $ 827,294 $ 7,617,457 $ 5,765,207
Well Services 6,672,156 11,910,560 17,697,866 24,527,444
Corporate
allocation &
eliminations (811,002) (1,382,737) (3,855,668) (6,188,740)
—————- ————– ————– ————– ————–
Total EBITDAX $ 6,279,248 $ 11,355,117 $ 21,459,655 $ 24,103,911

(a) Gas volumes are converted to BOE on the basis of 6 Mcf per 1 barrel.
(b) Finance expenses include accretion for asset retirement obligations.
(c) EBITDAX is a non-IFRS measure commonly used in the oil and gas
industry; see MD&A.

/T/

ABOUT ROOSTER ENERGY LTD.

Rooster Energy Ltd., is a Houston, Texas, based independent oil and natural gas
exploration and production company focused on the delivery of well intervention
services, including well plugging and abandonment, through its wholly owned
subsidiary, Morrison Well Services, LLC, and the development of resources in
the shallow waters of the Gulf of Mexico. Our primary assets consist of
rig-less plugging and abandonment spreads of well intervention equipment and
interests in oil and gas leases.

Investors are welcome to visit our website at www.roosterenergyltd.com.

Forward Looking Information and Statements

Certain statements and information in this press release may constitute
“forward-looking information” or statements as such terms are used in
applicable Canadian securities laws. Any statement that expresses, involves or
includes expectations of future operations (including drill rig commitments and
use of proceeds), commerciality of any hydrocarbon discovered, production
rates, operating costs, commodity prices, administrative costs, commodity price
risk and other components of cash flow and earnings, management activity,
acquisitions and dispositions, capital spending, access to credit facilities
taxes, regulatory changes, projections, objective, assumptions or future events
that are not statements of historical fact should be viewed as “forward-looking
statements”. Events or circumstances may cause actual results to differ
materially from those predicted, a result of numerous known and unknown risks,
uncertainties, and other factors, many of which are beyond the control of the
Company. These risks include, but are not limited to, the risks associated with
the oil and gas industry, commodity prices, and exchange rate changes. Industry
related risks could include, but are not limited to, operational risks in
exploration, development and production, delays or changes in plans, risks
associated with the uncertainty of reserve estimates, or reservoir performance,
health and safety risks and the uncertainty of estimates and projections of
production, costs and expenses. The reader is cautioned not to place undue
reliance on any forward-looking statement in this press release. The Company
disclaims any intention or obligation to update or revise any forward-looking
statement, whether as a result of new information, future events or otherwise,
except as required by applicable law.

Note Regarding Boe

The term barrel of oil equivalent (“boe”) may be misleading, particularly if
used in isolation. A conversion ratio for gas of 6 mcf//1 boe is based on an
energy equivalency conversion method primarily applicable at the burner tip and
does not represent a value equivalency at the wellhead. Given that the value
ratio based on the current price of crude oil as compared to natural gas is
significantly equivalency conversion ratio of 6:1, utilizing a conversion on a
6:1 basis is misleading as an indication of value.

NEITHER THE TSX VENTURE EXCHANGE NOR ITS REGULATION SERVICE PROVIDER (AS THAT
TERM IS DEFINED IN THE POLICIES OF THE TSX VENTURE EXCHANGE) ACCEPTS
RESPONSIBILITY FOR THE ADEQUACY OR ACCURACY OF THE RELEASE.

– END RELEASE – 28/04/2017

For further information:
Kenneth F. Tamplain, Jr.
Chief Executive Officer
Rooster Energy Ltd.
16285 Park Ten Place, Suite 120
Houston, Texas, USA 77084
Telephone: (832) 463-0625

COMPANY:
FOR: ROOSTER ENERGY LTD.
TSX VENTURE SYMBOL: COQ

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170428CC0096

Press Release from Marketwired 1-866-736-3779

All press releases are written by the client and have NO affiliation with the news copy written by The Canadian Press. Any questions that arise due to the content or information provided in the press release should be directed to the company/organization
issuing the release, not to The Canadian Press.

US rig count rises 13 this week to 870; Texas up 11

April 28, 2017 by The Canadian Press

HOUSTON — The number of rigs exploring for oil and natural gas in the U.S. rose by 13 this week to 870.

A year ago, 420 rigs were active.

Houston oilfield services company Baker Hughes Inc. said Friday that 697 rigs sought oil and 171 explored for natural gas this week. Two were listed as miscellaneous.

Texas added 11 rigs, Oklahoma gained three and Wyoming gained one.

New Mexico lost three rigs.

Alaska, Arkansas, California, Colorado, Kansas, Louisiana, North Dakota, Ohio, Pennsylvania, Utah and West Virginia were unchanged.

The U.S. rig count peaked at 4,530 in 1981. It bottomed out last May at 404.

The Associated Press

Alberta Energy Regulator says will appeal Redwater case to Supreme Court

April 28, 2017 by The Canadian Press

CALGARY — The Alberta Energy Regulator said Friday it will appeal to the Supreme Court of Canada a case that pits creditors’ rights to oil and gas assets against environmental liabilities.

The lawsuit involving bankrupt Redwater Energy Corp. has been closely watched as a precedent-setting case, as financial difficulties continue to afflict the oil and gas industry after more than two years of low commodity prices.

On Monday, the Alberta Court of Appeal upheld in a 2-1 decision a lower court’s ruling in favour of Grant Thornton, Redwater’s trustee in bankruptcy, and its lender, ATB Financial, who wanted to sell off its productive wells to pay creditors and leave the others for the industry-supported Orphan Well Association to remediate.

The AER argued funds from the sale of the productive wells must be used to cover cleanup expenses for the unproductive wells, a position backed by appeal interveners from the Alberta, B.C. and Saskatchewan governments as well as the Canadian Association of Petroleum Producers.

The regulator said it was disappointed by Monday’s decision, and will continue to press its case that the regulator is not acting as a creditor as it looks to protect the public and the environment.

In their majority decision, two of the appeal court judges found “no errors” in the Alberta Court of Queen’s Bench ruling in May 2016 that provincial regulations are in conflict with the federal Bankruptcy and Insolvency Act, and that the latter takes precedence.

The Canadian Press

Rooster Energy Ltd. Announces Executive Officer Changes

April 28, 2017 by The Canadian Press

FOR: ROOSTER ENERGY LTD.TSX VENTURE SYMBOL: COQDate issue: April 28, 2017Time in: 5:57 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 28, 2017) – ROOSTER ENERGY LTD. (the
“Company”) (www.roosterenergyltd.com) (TSX VENTURE:COQ) today announces t…

Wavefront Announces Second Quarter 2017 Financial Results

April 28, 2017 by The Canadian Press

FOR: WAVEFRONT TECHNOLOGY SOLUTIONS INC.
TSX VENTURE SYMBOL: WEE
OTCQX SYMBOL: WFTSF

Date issue: April 28, 2017
Time in: 5:54 PM e

Attention:

EDMONTON, ALBERTA–(Marketwired – April 28, 2017) – Wavefront Technology
Solutions Inc. (Wavefront or the Company) (TSX VENTURE:WEE)(OTCQX:WFTSF), an
Oil Field Service (“OFS”) provider focused on enhancing hydrocarbon recovery
through the lifecycle of a production asset, wishes to announce its financial
results for the second quarter ending February 28, 2017.

The financial highlights for the reporting period are as follows:

/T/

— Revenues for the six months ended February 28, 2017 were $1,114,732

compared to the comparative period ended February 29, 2016 that
recognized revenues of $1,446,544.

For the six months ended February 28, 2017, Powerwave revenues related
to well stimulations increased 115.0% or by $337,289 to $630,658,
compared to $293,370 in the comparative period. The increases over the
comparative quarter relates to the return of certain activity in
specific American markets, which increased by an approximated 106.8% or
$188,855, and an increase of approximately 278.5% or $176,718 in the
Middle East market.
— Revenues for the quarter (three months ended) February 28, 2017 were
$480,215, were relatively flat decreasing $51,698 over the comparative
quarter ended February 29, 2016 that recognized revenues of $531,913.

Powerwave revenues related to well stimulations for the second quarter
2017 increased by 128.7% or $110,409 to $196,198, compared to $85,789 in
the comparative quarter. Powerwave well stimulation revenue increased by
an approximated 163.4% in certain American markets, and in the Middle
East revenues increase by $70,357. Wavefront and its distribution
partners are making notable traction in attracting opportunities in the
Middle East with 21 pending Powerwave well stimulations.
— The basic and diluted net loss for the quarter ended February 28, 2017
was $930,635 ($0.01 per share), compared to $808,382 ($0.01 per share)
for the comparative quarter ended February 29, 2016.

/T/

The above financial highlights should be read in conjunction with the unaudited
condensed consolidated interim financial statements and the management
discussion and analysis of results for Wavefront for the second quarter ended
February 28, 2017, which were filed on SEDAR on April 28, 2017.

Subsequent to second quarter ended February 28, 2017, and as recently
announced, Wavefront’s distribution partner in Oman was awarded the approximate
$US 500,000 contract for expanded Powerwave use. This previously anticipated
Powerwave program was delayed due to lower and volatile oil prices over the
past few years. Powerwave deployment is in the client’s scheduling phase and is
anticipated to commence in the second half of calendar 2017.

ON BEHALF OF THE BOARD OF DIRECTORS, WAVEFRONT TECHNOLOGY SOLUTIONS INC.

D. Brad Paterson, CFO & Director

About Wavefront:

Wavefront is a technology based world leader in fluid injection technology for
improved/enhanced oil recovery and groundwater restoration. Wavefront publicly
trades on the TSX Venture Exchange under the symbol WEE and on the OTCQX under
the symbol WFTSF. The Company’s website is www.onthewavefront.com.

Cautionary Disclaimer – Forward Looking Statement

Certain statements contained herein regarding Wavefront and its operations
constitute “forward-looking statements” within the meaning of Canadian
securities laws and the United States Private Securities Litigation Reform Act
of 1995. All statements that are not historical facts, including without
limitation statements regarding future estimates, plans, objectives,
assumptions or expectations or future performance, are “forward-looking
statements”. In some cases, forward-looking statements can be identified by
terminology such as “may”, “will”, “should”, “expect”, “plan”, “anticipate”,
“believe”, “estimate”, “predict”, “potential”, “believe”, “continue” or the
negative of these terms or other comparable terminology. We caution that such
“forward-looking statements” involve known and unknown risks and uncertainties
that could cause actual results and future events to differ materially from
those anticipated in such statements. Such factors include fluctuations in the
acceptance rates of Wavefront’s Powerwave and Primawave Processes, demand for
products and services, fluctuations in the market for oil and gas related
products and services, the ability of Wavefront to attract and maintain key
personnel, technology changes, global political and economic conditions, and
other factors that were described in further detail in Wavefront’s continuous
disclosure filings, available on SEDAR at www.sedar.com. Wavefront expressly
disclaims any obligation to up-date any “forward-looking statements”, other
than as required by law.

From Bit To Last Drop(TM), WaveAxe(TM), Powerwave(TM) and Primawave(TM) are
registered trademarks of Wavefront Technology Solutions Inc., or its
subsidiaries, or affiliates.

NEITHER TSX VENTURE EXCHANGE NOR ITS REGULATION SERVICES PROVIDER (AS THAT TERM
IS DEFINED IN THE POLICIES OF THE TSX VENTURE EXCHANGE) ACCEPTS RESPONSIBILITY
FOR THE ADEQUACY OR ACCURACY OF THIS RELEASE.

– END RELEASE – 28/04/2017

For further information:
Wavefront Technology Solutions Inc.
D. Brad Paterson
CFO
780-486-2222
investor.info@onthewavefront.com
www.onthewavefront.com

COMPANY:
FOR: WAVEFRONT TECHNOLOGY SOLUTIONS INC.
TSX VENTURE SYMBOL: WEE
OTCQX SYMBOL: WFTSF

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170428CC0090

Press Release from Marketwired 1-866-736-3779

Canadian Equipment Rentals Corp. Closes Loan and Security Agreement with Maynbridge Capital Inc.

April 28, 2017 by The Canadian Press

FOR: CANADIAN EQUIPMENT RENTALS CORP.TSX VENTURE SYMBOL: CFLDate issue: April 28, 2017Time in: 5:30 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 28, 2017) – Canadian Equipment Rentals
Corp. (“CERC” or the “Company”) (TSX VENTURE:CFL) is pleas…

Greenfields Petroleum Corporation Announces Financial and Operating Results for the Year-Ended December 31, 2016

April 28, 2017 by The Canadian Press

FOR: GREENFIELDS PETROLEUM CORPORATION
TSX VENTURE SYMBOL: GNF

Date issue: April 28, 2017
Time in: 5:30 PM e

Attention:

HOUSTON, TEXAS–(Marketwired – April 28, 2017) – Greenfields Petroleum
Corporation (the “Company” or “Greenfields”) (TSX VENTURE:GNF) is pleased to
report its financial and operating results for the fourth quarter and
year-ended December 31, 2016. Selected financial and operational information is
set forth below and should be read in conjunction with the Company’s December
31, 2016 audited annual financial statements and the related management’s
discussion and analysis (“MD&A”). Also, the Company today announces the filing
of its Annual Information Form (“AIF”) for the year-ended December 31, 2016
which contains the Company’s reserves data and other oil and natural gas
information, as required under National Instrument 51-101. The AIF, financial
statements and MD&A are available for review at www.sedar.com or on the
Company’s website at www.greenfields-petroleum.com.

Except as otherwise indicated, all dollar amounts referenced herein are
expressed in United States dollars.

Fourth Quarter and 2016 Fiscal Year Financial Results and Operating Highlights

/T/

— Bahar Energy Limited’s (“BEL”) entitlement sales volumes averaged 647

bbl/d for crude oil and 17,403 mcf/d for natural gas or 3,547 boe/d in
the fourth quarter and 764 bbl/d for crude oil and 15,691 mcf/d for
natural gas or 3,379 boe/d for 2016. In comparison to the average
volumes for the same quarter in 2015, volumes decreased 37% for oil,
increased 16% for natural gas and no change for boe/d, respectively.
2016 average volumes decreased 26% for oil, increased 6% for natural gas
and decreased 4% for boe/d, respectively, when compared to 2015.

— The Company’s share of BEL entitlement sales volumes averaged 647 bbl/d

for crude oil and 17,403 mcf/d for natural gas or 3,547 boe/d in the
fourth quarter and 443 bbl/d for crude oil and 9,833 mcf/d for natural
gas or 2,082 boe/d for 2016. 2016 volumes include the Company’s 33.33%
share of BEL held prior to the completion of the acquisition of Baghlan
Group Limited’s (“Baghlan”) 66.67% interest in BEL on August 9, 2016 and
100% of BEL from acquisition date.

— For the fourth quarter and 2016 fiscal year, BEL realized an average oil

price of $42.99 and $37.52, respectively. This reflects an increase from
$31.60 per barrel and a decrease from $43.57 per barrel, respectively,
for the same periods in 2015. BEL realized an average natural gas price
of $3.96 per mcf for 2016 and 2015, which was a contractually constant
fixed price.

— For the fourth quarter and 2016 fiscal year, the Company realized a loss

of $4.6 million and income of $99.2 million, respectively, which
represents income (loss) per share (basic and diluted) of ($0.03) and
$1.52, respectively. For 2016, income included $113.6 million of one-
time net realized gains attributable to acquisition and restructuring
transactions. Excluding this one-time gain, the Company realized a loss
of $14.4 million or $0.22 per share. In comparison with the same periods
in 2015, the Company realized net losses of $1.5 million and $7.5
million, respectively, with a loss per share of $0.07 and $0.34,
respectively.

/T/

Operating Highlights and Plans

/T/

— Gross production from the exploration, rehabilitation, development and

production sharing agreement (“ERDPSA”) averaged 784 bbl/d for crude
oil, 20.8 mmcf/d for natural gas or 4,251 boe/d for the fourth quarter
and 884 bbl/d for crude oil, 18.3 mmcf/d for natural gas or 4,167 boe/d
for 2016. Production was impacted by the slower pace of executing
scheduled workovers due to limited availability of crane barges as well
as lower than expected post-workover production results.

— During the fourth quarter and 2016 fiscal year, operating expenses were

mainly in line with budget while capital expenditures were significantly
under budget as a result of capital projects being reduced in scope or
delayed.

— In the Gum Deniz Oil Field, Bahar Energy Operating Company (“BEOC”)

completed six capital workovers during the fourth quarter and a total of
eleven for 2016. BEOC also completed thirteen service workovers during
the fourth quarter and a total of forty for 2016.

— In the Bahar Gas Field, BEOC completed four capital workovers during the

fourth quarter and a total of eight for 2016. Three of these capital
workovers were initiated using a limited capacity A-80 rig. A tender is
underway for heavier workover rigs which will allow more aggressive
fishing jobs and well clean out.

— In 2016, BEOC continued progress on several construction projects

including platform refurbishment, causeway structure reinforcement and
facility and HSE upgrades. With the exception of scaffolding services,
BEOC’s construction department performed all work, eliminating the need
for third party contractors which resulted in improved efficiency and
lower costs.

— Reservoir simulation model studies continue for both Bahar and Gum Deniz

fields and are expected to be completed in mid-2017. The results of
these simulation studies will serve as the basis for future development
plans in both fields.

— On March 3, 2017, BEOC signed an amendment to the gas sales agreement

(the “Amended GSA”) for the sale of non-associated natural gas produced
under the ERDPSA with the State Oil Company of the Republic of
Azerbaijan (“SOCAR”) in Azerbaijan.

The original gas sales agreement (the “Original GSA”) for the sale of
non-associated natural gas from the Bahar Gas Field expired on October
1, 2015. Natural gas sales continued on a month to month basis on
original terms set forth in the Original GSA while a revised gas sales
agreement was negotiated with SOCAR. With the continued difficult
economic conditions in Azerbaijan due to low oil prices, SOCAR has
placed pressure on all production sharing agreement holders to lower
prices for natural gas sold to SOCAR for domestic consumption. The
Amended GSA, effective from April 1, 2017, extends the term of the
arrangement by 5 years and establishes a fixed natural gas price of
$95/mcm ($2.69/mcf), which is reduced from the natural gas price of
$140/mcm ($3.96/mcf) established by the Original GSA.

In addition, the Amended GSA expands SOCAR’s obligation to purchase non-
associated natural gas. Under the terms of the Original GSA, SOCAR
purchased only non-associated natural gas from Bahar Gas Field. Under
the terms of the Amended GSA, SOCAR will also purchase non-associated
natural gas from the entire ERDPSA area.

— On April 19, 2017 BEL and SOCAR signed a protocol in respect of the

carry of certain costs and related issues (the “Protocol”) which
addresses the shortfall by SOCAR Oil Affiliate (“SOA”) in funding its
20% share of project expenditures incurred under the ERDPSA since April
2014. Per the Protocol, any funding by BEL of the deficiencies in SOA’s
cash call payments will be added to the outstanding Carry 1 balance and
subsequently reimbursed in accordance with the terms of the ERDPSA
through payment of SOA’s share of cost recovery revenues to BEL.

— Considering the new lower gas pricing terms from April 2017, BEOC is

planning to focus on increasing gas production from the Bahar Gas Field
through a series of recompletions of existing wells to improve project
cash flows. Additionally, BEOC will initiate programs to further reduce
field operating costs while maintaining HS&E standards. The completion
of the detailed reservoir engineering modeling will provide for a
revised Plan of Development for the Bahar and Gum Deniz fields which is
focused on long term development of oil and natural gas resources and
alternatives for testing exploration opportunities identified on the
recently acquired 3D Seismic.

/T/

Selected Financial Information

The selected information below is from the MD&A. The Company’s complete
financial statements as of and for the years ended December 31, 2016 and 2015,
with the notes thereto and the related MD&A can be found either on Greenfields’
website at www.Greenfields-Petroleum.com or on SEDAR at www.sedar.com.

Revenues and operating results in the “Selected Financial Information” have
been adjusted to reflect the Company’s share of BEL. Upon closing the
acquisition of Baghlan Group Limited’s 66.67% interest in BEL on August 9, 2016
(the “Acquisition”) and BEL becoming a wholly-owned subsidiary, the Company
consolidates the revenues and operating results from BEL on a going forward
basis. Revenues, entitlement sales volumes and operating results presented in
these tables have been adjusted to include the Company’s 33.33% share of
petroleum, natural gas and transportation revenues from BEL, previously
included in the income or loss on Investment in Joint Venture under the equity
method of accounting through August 8, 2016, combined with the Company’s 100%
share of BEL consolidated from the August 9, 2016 acquisition date. The
combined financial and operating results have been presented only for
comparative purposes and does not reflect proper accounting practices under
GAAP.

Greenfields Petroleum Corporation

All amounts below are in thousands of US dollars unless otherwise noted.

/T/

—————————————————————————-

Year ended
(US$000’s, except as noted) December 31,
2016 2015
—————————————————————————-
Financial

Revenues 21,592 14,657
Net income (loss) (1) 99,193 (7,524)
Per share, basic and diluted $1.52 ($0.34)

—————————————————————————-
Capital items

Cash and cash equivalents 1,361 100
Total assets 199,341 89,523
Working capital (1,444) (6,478)
Long term debt and shareholders’ equity 185,103 55,600
—————————————————————————-
—————————————————————————-

/T/

(1) For the 2016 fiscal year, $113.6 million of net realized gains from the
Acquisition and the debt restructuring transactions were included in income.

Bahar Energy Limited

/T/

—————————————————————————-

Company’s share
—————————————-
(US$000’s, except as noted) Year ended December 31,
—————————————-
2016 2015 2016 2015
—————————————————————————-
Financial

Revenues 33,507 39,313 20,783 13,103

—————————————————————————-
Operating

Average Entitlement Sales Volumes
(1)
Oil and condensate (bbl/d) 764 1,033 443 344
Natural gas (mcf/d) 15,691 14,837 9,833 4,945
Barrel oil equivalent (boe/d) 3,379 3,506 2,082 1,169

Average Oil Price
Oil price ($/bbl) $ 38.44 $ 44.82 $ 38.44 $ 44.82
Net realization price ($/bbl) $ 37.52 $ 43.57 $ 37.52 $ 43.57
Brent oil price ($/bbl) $ 43.67 $ 52.42 $ 43.67 $ 52.42

Natural gas price ($/mcf) $ 3.96 $ 3.96 $ 3.96 $ 3.96

—————————————————————————-
—————————————————————————-

/T/

(1) Daily volumes represent the Company’s share of the entitlement volumes of
the contractor parties to the ERDPSA net of compensatory petroleum and the
government’s share of profit petroleum. Compensatory petroleum represents 10%
of gross production and continues to be delivered until specific cumulative
petroleum and natural gas production milestones are attained. Daily volumes for
the year ended December 31, 2016 include the Company’s 33.33% share of BEL
entitlement volumes through August 8, 2016 and from August 9, 2016 through
December 31, 2016, 100% of BEL’s entitlement volumes resulting from the
Acquisition.

About Greenfields Petroleum Corporation

Greenfields is a junior oil and natural gas company focused on the development
and production of proven oil and gas reserves principally in the Republic of
Azerbaijan. The Company plans to expand its oil and gas assets through further
farm-ins, and acquisitions of Production Sharing Agreements from foreign
governments containing previously discovered but under-developed international
oil and gas fields, also known as “greenfields”. More information about the
Company may be obtained on the Greenfields website at
www.greenfields-petroleum.com.

Forward-Looking Statements

This press release contains forward-looking statements. More particularly, this
press release may include, but is not limited to, statements concerning:
operational plans; the Bahar and Gum Deniz field studies and the expectations
in relation thereto; production; and programs initiated by BEOC. In addition,
the use of any of the words “initial, “scheduled”, “can”, “will”, “prior to”,
“estimate”, “anticipate”, “believe”, “should”, “forecast”, “future”,
“continue”, “may”, “expect”, and similar expressions are intended to identify
forward-looking statements. The forward-looking statements contained herein are
based on certain key expectations and assumptions made by the Company,
including, but not limited to, expectations and assumptions concerning the
success of optimization and efficiency improvement projects, the availability
of capital, current legislation, receipt of required regulatory approval, the
success of future drilling and development activities, the performance of
existing wells, the performance of new wells, general economic conditions,
availability of required equipment and services, weather conditions and
prevailing commodity prices. Although the Company believes that the
expectations and assumptions on which the forward-looking statements are based
are reasonable, undue reliance should not be placed on the forward-looking
statements because the Company can give no assurance that they will prove to be
correct.

Since forward-looking statements address future events and conditions, by their
very nature they involve inherent risks and uncertainties most of which are
beyond the control of Greenfields. Should one or more of these risks or
uncertainties materialize, or should assumptions underlying the forward-looking
information prove incorrect, actual results, performance or achievements could
vary materially from those expressed or implied by the forward-looking
information. These risks include, but are not limited to, risks associated with
the oil and gas industry in general (e.g., operational risks in development,
exploration and production; delays or changes in plans with respect to
exploration or development projects or capital expenditures; the uncertainty of
reserve estimates; the uncertainty of estimates and projections relating to
production, costs and expenses, and health, safety, political and environmental
risks), commodity price and exchange rate fluctuations, changes in legislation
affecting the oil and gas industry and uncertainties resulting from potential
delays or changes in plans with respect to exploration or development projects
or capital expenditures. Additional risk factors can be found under the heading
“Risk Factors” in Greenfields’ Annual Information Form and similar headings in
Greenfields’ Management’s Discussion & Analysis which may be viewed on
www.sedar.com.

The forward-looking statements contained in this press release are made as of
the date hereof and Greenfields undertakes no obligation to update publicly or
revise any forward-looking statements or information, whether as a result of
new information, future events or otherwise, unless so required by applicable
securities laws. The Company’s forward-looking information is expressly
qualified in its entirety by this cautionary statement.

Notes to Oil and Gas Disclosures

Barrels Oil Equivalent or “boe” may be misleading, particularly if used in
isolation. The volumes disclosed in this press release under the headings
“Financial Results and Operating Highlights” and “Selected Financial
Information” use a 6mcf: 1boe, as such is typically used in oil and gas
reporting and is based on an energy equivalency conversion method primarily
applicable at the burner tip and does not represent a value equivalency at the
wellhead. The Company uses a 6mcf: 1boe ratio to calculate its share of
entitlement sales from the Bahar Project for its financial reporting and
reserves disclosure.

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that
term is defined in the policies of the TSX Venture Exchange) accepts
responsibility for the adequacy or accuracy of this release.

– END RELEASE – 28/04/2017

For further information:
Greenfields Petroleum Corporation
John W. Harkins
Chief Executive Officer
(832) 234-0836
OR
Greenfields Petroleum Corporation
A. Wayne Curzadd
Chief Financial Officer
(832) 234-0835
info@greenfieldspetroleum.com
www.greenfields-petroleum.com

COMPANY:
FOR: GREENFIELDS PETROLEUM CORPORATION
TSX VENTURE SYMBOL: GNF

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170428CC0085

Press Release from Marketwired 1-866-736-3779

The Latest: Trump signs order to expand ocean oil drilling

April 28, 2017 by The Canadian Press

WASHINGTON — The Latest on an executive order that could lead to expansion of drilling in the Arctic and Atlantic oceans (all times local):

11:40 a.m.

President Donald Trump has signed an executive order that will roll back restrictions on oil drilling in the Arctic.

Trump says at a White House signing ceremony, “Today, we’re unleashing American energy and clearing the way for thousands and thousands of high-paying energy jobs.”

The order also directs his energy secretary to review regulations overseeing drilling and former President Barack Obama’s five-year drilling plan.

It’s Trump’s latest move to undo his predecessor’s environmental protection efforts in his first 100 days in office.

The Associated Press

Tornado Global Hydrovacs Reports 2016 Results

April 28, 2017 by The Canadian Press

FOR: TORNADO GLOBAL HYDROVACS LTD.
TSX VENTURE SYMBOL: TGH

Date issue: April 28, 2017
Time in: 5:00 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 28, 2017) – Tornado Global Hydrovacs
Ltd. (“Tornado” or the “Company”) (TSX VENTURE:TGH) today reported its audited
consolidated financial results for the fiscal year ended December 31, 2016. The
audited consolidated financial statements and MD&A have been filed on SEDAR and
can be reviewed at www.sedar.com.

Summary of 2016 consolidated annual results

/T/

— Revenues decreased by $3.1 million (15.5%), to $17.0 million from $20.1

million in 2015. The decrease in revenue was attributed to the continued
decline in demand for hydrovac trucks caused by low oil prices and the
corresponding reduction in oil production and associated capital
expenditures.
— Adjusted EBITDA decreased by $2.0 million, to a loss of $2.1 million
from a loss of $0.1 million in 2015. The reduction was driven by price
pressures arising from the drop in overall demand for hydrovac trucks,
less cost efficiencies at lower production volumes, our new truck design
not going into production until late in the fourth quarter and a $0.9
million increase in overhead due to the Company’s expansion into China
and operating as a stand-along public Company along with these
associated costs.
— Net Loss of $2.7 million in 2016 compared to a Net loss of $0.9 million
in 2015. The majority of this decrease was a result of factors discussed
above. Tornado’s depreciation and amortization expense was $0.4 million
higher than the prior year. The increased depreciation and amortization
expense resulted from certain items of property and equipment and
intangible assets being marked to fair value because of the acquisition
of the assets and liabilities of Tornado Trucks. This increase in
depreciation and amortization was offset by a $0.5 million reduction in
Former Parent management fee.
— Net Loss was $929 ($0.016 per share) in the fourth quarter of 2016 which
was a slight improvement over the Net Loss of $999 ($0.017 per share) in
the third quarter of 2016.

—————————————————————————-
—————————————————————————-
Periods ended December 31 Twelve months ended Quarter ended
————————————————–
2016 2015 Variance 2016 2015 Variance
($000’s, except for
percentages) $ $ $ $ $ $
—————————————————————————-
—————————————————————————-

Operating Results:

Revenues 17,049 20,178 -3,129 4,975 5,151 -176
Adjusted EBITDA (loss) -2,088 -126 -1,962 -528 4 -532
Adjusted EBITDA% -12.3% -0.6% -11.7% -10.6% 0.1% -10.7%
Net Income (loss) -2,751 -887 -1864 -929 -370 -559
Net Income (loss) per
share $-0.046 NA NA $-0.016 NA NA
—————————————————————————-
—————————————————————————-

/T/

The operational results for the hydrovac business for the period of January 1,
2016 to June 28, 2016 were prior to the acquisition and were to the account of
the former owner, Empire Industries Ltd. and the post acquisition was to the
account of the Company. A breakdown of the 2016 Operating Results between the
pre-acquisition and post-acquisition periods is outlined in the table below:

/T/

—————————————————————————-
—————————————————————————-

2016 Operating Results Pre- Post-
Acquisition Acquisition 2016
(presented in $000’s) $ $ $
—————————————————————————-
—————————————————————————-

Operating Results:

Revenue 9,146 7,903 17,049
—————————————————————————-
Adjusted EBITDA (721) (1,367) (2,088)
—————————————————————————-
Net Income (Loss) (823) (1,928) (2,751)
—————————————————————————-

/T/

The Fourth Quarter 2016 Adjusted EBITDA loss was reduced to $528 from the Third
Quarter EBITDA Loss which was $840. It is also important to note that there was
a $552 loss on starting operations in China which was largely incurred in the
Fourth Quarter of 2016. This means that the North American operations were
returning to profitability in the Fourth Quarter.

/T/

—————————————————————————-
—————————————————————————-

31-Dec 31-Dec
(presented in $000’s) 2016 2015
—————————————————————————-
—————————————————————————-
Financial Position
Total assets $19,539 $8,682
Long-term debt (including current portion) $2,535 $35
Shareholders’ equity $13,355 $7,054
Shares Outstanding (Basic) 59,481 NA
Shareholders’ equity per share $0.22 NA
—————————————————————————-
—————————————————————————-

/T/

Adjusted earnings (loss) before interest, tax, depreciation and amortization
(Adjusted EBITDA) is not defined by IFRS. The definition of Adjusted EBITDA
does not consider gains and losses on the disposal of assets, fair value
changes in foreign currency forward contracts and non-cash components of stock
based compensation. While not IFRS measures, Adjusted EBITDA is used by
management, creditors, analysts, investors and other financial stakeholders to
assess the Group’s performance and management from a financial and operational
perspective.

Management believes that 2017 will be a positive year for its North America
operation and a building year for its Chinese operation. In North America, we
have experienced improvement in the hydrovac market equipment purchase demand
with increased interest coming out of the municipal sector. There are three
primary reasons for this increased demand for hydrovacs;

/T/

— there have been a number of announcements from both the US and Canadian

governments calling for a material increase to infrastructure spending
going forward.
— Tornado Global Hydrovac’s new, patent pending design, has compelling
advantages over our competitors’ trucks and this new truck only came on
the market in the fourth quarter of 2016.
— there continue to be thousands of utility “line-strikes” in the gas,
fiber-optics and electrical underground infrastructure market every year
in North America which is driving the need for our technology and
products.

/T/

As a consequence, the Company is seeing an improvement in its financial
performance in 2017 with this increase in market demand and specific demand for
its patent pending design.

In China, we continue to execute our plan to develop and penetrate this
significant market. The highlights of both what we have achieved to date and
are targeting to achieve in 2017 include:

/T/

— We expect to be in a position to manufacture our hydrovac trucks in

China early in 2018.
— We currently have seven employees in our Beijing office which will
continue to grow once production begins in early 2018. We anticipate a
growing market for our trucks once we establish our presence and prove
up the needs for hydrovac trucks in China.
— We have designed and manufactured three hydrovac trucks for use in China
out of our Canadian manufacturing plant. We anticipate that they will
land in China before the end of second quarter and be used for market
demonstration in China.
— We are in the final stages of completing the required inspections from
the Chinese authorities for manufacturing hydrovac trucks in China.

/T/

Having completed its spin-out of its former parent company, management believes
the medium and long term outlook for the Company is positive and improving both
in North America and China. Management believes that the Company is now
positioned to focus efforts on developing the China market which it views as
having significant potential.

About Tornado Global Hydrovacs Ltd.

The Company designs, manufactures and sells hydrovac trucks for excavation
service providers to the oil and gas industry and the municipal markets.
Hydrovac trucks use high pressure water to pulverize soil and turn it into mud,
and then vacuum up the resulting mud into its tank. Tornado currently operates
in North America and intends to expand its hydrovac business into China.

Advisory

The Exchange has in no way passed upon the merits of the proposed transaction
and has neither approved nor disapproved the contents of this press release.

Neither the Exchange nor its Regulation Service Provider (as that term is
defined in policies of the Exchange) accepts responsibility for the adequacy or
accuracy of this news release.

Certain statements contained in this news release constitute forward-looking
statements. These statements relate to future events. All statements other than
statements of historical fact are forward-looking statements. The use of the
words “may”, “expected”, “believes”, “anticipates” and other words of a similar
nature are intended to identify forward-looking statements. These statements
involve known and unknown risks, uncertainties and other factors that may cause
actual results or events to differ materially from those anticipated in such
forward-looking statements. Although the Company believes these statements to
be reasonable, no assurance can be given that these expectations will prove to
be correct and such forward-looking statements included in this news release
should not be unduly relied upon. Such statements include statements with
respect to the outlook of the Company, the market for hydrovac trucks in North
America and China, and anticipated effect of the Company’s newly designed
hydrovac truck. Actual results could differ materially from those anticipated
in these forward-looking statements as a result of prevailing economic
conditions, receipt of requisite regulatory approvals, and other factors, many
of which are beyond the control of the Company. The forward-looking statements
contained in this news release represent the Company’s expectations as of the
date hereof, and are subject to change after such date. The Company disclaims
any intention or obligation to update or revise any forward-looking statements
whether as a result of new information, future events or otherwise, except as
may be required by applicable securities regulations.

– END RELEASE – 28/04/2017

For further information:
Tornado Global Hydrovacs Ltd.
Bill Rollins
Chief Executive Officer
(403) 204-6333
brollins@tghl.ca
www.tornadotrucks.com

COMPANY:
FOR: TORNADO GLOBAL HYDROVACS LTD.
TSX VENTURE SYMBOL: TGH

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas , Transportation and Logistics – Trucking
RELEASE ID: 20170428CC0074

Press Release from Marketwired 1-866-736-3779

Imperial Oil CEO defends absence from oilsands consolidation trend

April 28, 2017April 28, 2017 by The Canadian Press

CALGARY — CEO Rich Kruger said Friday his company has not been idle while other major Canadian producers snapped up oilsands assets from foreign rivals over the past year.

The head of Imperial Oil (TSX:IMO) said the Calgary-based company, one of the top four oilsands producers in Canada, has been busy building and commissioning its Kearl oilsands mining project where the first phase started in 2013 and the second phase in 2015. It has also been dealing with operational issues at its Nabiye steam-driven oilsands project, which started production in 2015.

“We’ve just completed an unprecedented period of upstream growth with two phases of Kearl, with Nabiye,” he told reporters after the company’s annual meeting of shareholders.

“We have commented several times on how we’re progressing the technical and commercial project opportunities for readiness. So I wouldn’t describe it as ‘on the sidelines.'”

Last month, Royal Dutch Shell announced it had agreed to sell most of its Canadian oilsands assets to Canadian Natural Resources (TSX:CNQ) for about C$11.1 billion, while Cenovus Energy (TSX:CVE) unveiled a $17.7-billion deal to buy most of the Canadian assets of Houston-based ConocoPhillips, including its half interest in jointly owned oilsands assets.

Calgary-based Suncor Energy (TSX:SU) last year increased its ownership of Syncrude Canada from 12 per cent to over 53 per cent by buying Canadian Oil Sands for $6.6 billion in cash and assumed debt, and adding Murphy Oil’s interest for $937 million.

At its annual meeting on Thursday, Suncor CEO Steve Williams said he expects more foreign companies will sell oilsands stakes, citing Chevron, BP and Total as names that are said to be interested in selling.

Oilsands analyst Michael Dunn of GMP FirstEnergy said he agrees that the consolidation isn’t over yet, adding there were strategic reasons for the other Canadian oilsands buyers to make the deals they made.

He pointed out that Imperial, which is 69.6 per cent owned by American oil giant Exxon Mobil, has previously indicated it would prefer to buy large-scale, high-quality, non-mining oilsands resources, implying a preference for undeveloped projects.

Kruger said Imperial keeps its mergers and acquisition plans “close to chest” but is watching for opportunities to add value from internal projects or through acquisition.

Imperial on Friday reported first-quarter net income of $333 million or 39 cents per share in the three months ended March 31, boosted by a gain of $151 million on the sale of former refinery lands in Mississauga, Ont., compared with a loss of $101 million or 12 cents in the year-earlier period.

Operating earnings per share were 21 cents, versus consensus analyst expectations of 40 cents.

The company says it will increase its quarterly dividend in June by a penny to 16 cents per share.

Total revenue was up 37 per cent to $7.16 billion.

Production averaged 378,000 barrels of oil equivalent per day, compared to 421,000 boe/d in the same period of 2016, due in part to a fire at the Syncrude Mildred Lake upgrader in mid-March which affected production.

Imperial owns 25 per cent of Syncrude.

Follow @HealingSlowly on Twitter.

Dan Healing, The Canadian Press

Exxon Mobil’s 1Q profit more than doubles

April 28, 2017April 28, 2017 by The Canadian Press

IRVING, Texas — Exxon more than doubled its profit in the first quarter as rising crude prices magnified the cost cuts made by the company as energy prices tumbled.

The company earned $4.01 billion, or 95 cents per share, for the three month period. A year earlier the Irving, Texas, company earned $1.81 billion, or 43 cents per share, as oil and gas prices sank.

Analysts surveyed by Zacks Investment Research expected 85 cents per share. Exxon does not adjust its reported results based on one-time events such as asset sales.

Shares of Mobil Corp. climbed almost 2 per cent in Friday premarket trading, but are still down 10 per cent for the year.

A barrel of U.S. crude was trading for less than $50 Friday, a third of what it cost five years ago and prices are down almost 8 per cent this year after they began sliding again this month.

Exxon’s revenue surged to $63.29 billion from $48.71 billion, but fell short of the $64.35 billion that analysts polled by Zacks were calling for.

Last month Exxon’s new CEO Darren Woods said that the company would increase production and has a mix of projects to handle any level of oil and gas prices. Woods rose to Exxon’s top job two months ago after his predecessor, Rex Tillerson, was named secretary of state by then-President-elect Donald Trump.

_____

Elements of this story were generated by Automated Insights (http://automatedinsights.com/ap) using data from Zacks Investment Research. Access a Zacks stock report on XOM at https://www.zacks.com/ap/XOM

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Keywords: Exxon Mobil, Earnings Report, Priority Earnings

The Associated Press

Trump seeks to expand drilling in Arctic, Atlantic oceans

April 28, 2017April 28, 2017 by The Canadian Press

WASHINGTON — Working to dismantle his predecessor’s environmental legacy, President Donald Trump plans to sign an executive order Friday that could lead to the expansion of drilling in the Arctic and Atlantic oceans.

With one day left to rack up accomplishments before he reaches his 100th day in office, Trump will order his interior secretary to review an Obama-era plan that dictates which locations are open to offshore drilling, with the goal of the new administration to expand operations.

It’s part of Trump’s promise to unleash the nation’s energy reserves in an effort to reduce reliance on foreign oil and to spur jobs, regardless of fierce opposition from environmental activists who say offshore drilling harms whales, walruses and other wildlife and exacerbates global warming.

“This order will cement our nation’s position as a global energy leader and foster energy security for the benefit of American people, without removing any of the stringent environmental safeguards that are currently in place,” Interior Secretary Ryan Zinke told reporters at a White House briefing Thursday evening.

Zinke said the order, combined with other steps Trump has taken during his first months in office, “puts us on track for American energy independence.”

The executive order will reverse part of a December effort by President Barack Obama to deem the bulk of U.S.-owned waters in the Arctic Ocean and certain areas in the Atlantic as indefinitely off limits to oil and gas leasing.

It will also direct Zinke to conduct a review of the locations available for offshore drilling under a five-year plan signed by Obama in November. The plan blocked new oil and gas drilling in the Atlantic and Arctic oceans. It also blocked the planned sale of new oil and gas drilling rights in the Chukchi and Beaufort seas north of Alaska, but allowed drilling to go forward in Alaska’s Cook Inlet southwest of Anchorage.

The order could open to oil and gas exploration areas off Virginia and North and South Carolina, where drilling has been blocked for decades.

Zinke said that leases scheduled under the existing plan will remain in effect during the review, which he estimated will take several years.

The order will also direct Commerce Secretary Wilbur Ross to conduct a review of marine monuments and sanctuaries designated over the last 10 years.

Citing his department’s data, Zinke said the Interior Department oversees some 1.7 billion acres on the outer continental shelf, which contains an estimated 90 billion barrels of undiscovered oil and 327 trillion cubic feet of undiscovered natural gas. Under current restrictions, about 94 per cent of that outer continental shelf is off-limits to drilling.

Zinke, who will also be tasked with reviewing other drilling restrictions, acknowledged environmental concerns as “valid,” but he argued that the benefits of drilling outweigh concerns.

Environmental activists, meanwhile, railed against the expected signing, which comes seven years after the devastating 2010 BP oil spill in the Gulf of Mexico.

Diana Best of Greenpeace said that opening new areas to offshore oil and gas drilling would lock the U.S. “into decades of harmful pollution, devastating spills like the Deepwater Horizon tragedy, and a fossil fuel economy with no future.

“Scientific consensus is that the vast majority of known fossil fuel reserves – including the oil and gas off U.S. coasts- must remain undeveloped if we are to avoid the worst effects of climate change,” she said.

Jacqueline Savitz of the ocean advocacy group Oceana warned the order would lead to “corner-cutting and set us up for another havoc-wreaking environmental disaster” in places like the Outer Banks or in remote Barrow, Alaska, “where there’s no proven way to remove oil from sea ice.”

“We need smart, tough standards to ensure that energy companies are not operating out of control,” she said, adding: “In their absence, America’s future promises more oil spills and industrialized coastlines.”

___

Follow Matthew Daly and Jill Colvin on Twitter at http://twitter.com/MatthewDalyWDC and https://twitter.com/colvinj

Matthew Daly And Jill Colvin, The Associated Press

Nesscap Completes Arrangement with Maxwell

April 28, 2017 by The Canadian Press

FOR: NESSCAP ENERGY INC.TSX VENTURE SYMBOL: NCEDate issue: April 28, 2017Time in: 10:54 AM eAttention:
TORONTO, ONTARIO–(Marketwired – April 28, 2017) – Nesscap Energy Inc. (the
“Company” or “Nesscap”) (TSX VENTURE:NCE), is pleased to announce that i…

PetroShale Announces Financial, Operating and Reserves Update and Year Ended December 31, 2016 Results

April 28, 2017 by The Canadian Press

FOR: PETROSHALE INC.
TSX VENTURE SYMBOL: PSH
OTCQX SYMBOL: PSHIF

Date issue: April 28, 2017
Time in: 9:00 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 28, 2017) – PetroShale Inc.
(“PetroShale” or the “Company”) (TSX VENTURE:PSH)(OTCQX:PSHIF) is pleased to
announce its financial and operating results for the three and twelve month
periods ended December 31, 2016, along with updated reserves as at December 31,
2016.

PetroShale will file its audited consolidated financial statements and the
corresponding Management’s Discussion and Analysis (“MD&A”) as at and for the
year ended December 31, 2016, as well as its 2016 Annual Information Form
including its year end reserves disclosures, on SEDAR at www.sedar.com, on the
OTCQX website at www.otcqx.com, and post the information on our website at
www.petroshaleinc.com. Copies of the materials can also be obtained upon
request without charge by contacting the Company directly.

HIGHLIGHTS:

PetroShale continued to focus on acquiring and developing land in the core of
the North Dakota Bakken / Three Forks play. We took the first step in
developing our operated drilling unit by drilling and completing a well in the
prolific Antelope area, and continued to realize production growth from our
non-operated interests where we are partnered with some of the largest and most
experienced operators in the basin. Our continued operational success and
completion of an equity financing earlier this month have positioned us to be
more aggressive in increasing production and drilling inventory targets as we
move forward.

The Company’s achievements since 2015 include the following:

/T/

— Successfully drilled and completed the first well on our operated unit

(73.4% working interest) in the Antelope area which commenced production
on December 31, 2016, and participated in three gross (0.7 net) non-
operated wells in December, which have resulted in a substantial
increase in current production to approximately 2,800 boe per day.
— Achieved a significant increase in oil and natural gas reserves and
estimated net present value (discounted at 10% – “NPV10”) across all
categories at year end 2016 compared to December 31, 2015:
— Total proved plus probable (“P+P”) reserves increased 23% to 31.5
million boe (“Mmboe”), from 25.5 Mmboe.
— NPV10 of the P+P reserves increased 29% to US$399.5 million,
compared to US$308.7 million, despite a reduction in estimated
future commodity prices.
— Generated operating netbacks of $20.14 per boe in 2016 (Company
interest, gross of royalty; $25.34 per boe net of royalty), despite an
11% reduction in the benchmark price of crude oil (WTI) to US$43.31,
reflecting our high-quality, light oil weighted asset base.
— Realized EBITDA of $9.5 million in 2016.
— Participated in 64 gross (2.6 net) wells at various stages of
completion, for total capital expenditures of $20.9 million, and
purchased oil and gas leases within PetroShale’s core focus areas which
included a total of 351 net acres of land for a total cost of
approximately $8.5 million.
— Closed, in April 2017, a fully subscribed equity offering (including
full exercise of the over-allotment option) that generated net proceeds
of $106 million.
— Increased the borrowing capacity under our senior credit facility to
US$30.9 million, from US$23.7 million, and extended the renewal date to
February 28, 2018. The conclusion of the equity offering and the
increase in the senior credit facility borrowing base leaves us with
approximately US$79 million of undrawn credit capacity under our senior
and subordinated credit facilities.

/T/

RESULTS OF OIL AND GAS ACTIVITIES

/T/

Three months ended Twelve months ended
—————————————————————————-
December 31, December 31, December 31, December 31,
2016 2015 2016 2015
—————————————————————————-
Sales volumes
—————————————————————————-
Crude Oil (Bbl/d) 1,325 1,278 1,221 1,202
Natural gas and NGLs
(Mcf/d) 3,218 993 2,458 802
—————————————————————————-
Barrel of oil equivalent
(Boe/d) 1,861 1,444 1,631 1,336

Operating Netbacks
($/Boe)(1)
—————————————————————————-

Revenue $ 44.67 $ 42.23 $ 38.95 $ 47.11
Royalties (9.39) (9.02) (7.99) (10.34)
Operating costs (7.63) (6.22) (7.86) (7.32)
Production taxes (3.30) (3.60) (2.96) (3.79)
—————————————————————————-
Operating netback $ 24.35 $ 23.39 $ 20.14 $ 25.66
Operating netback, on a
net of royalty basis $ 30.86 $ 29.69 $ 25.34 $ 32.89
—————————————————————————-
Note:
(1) See “Oil and Gas Advisories”.

/T/

2016 YEAR-END RESERVES

The reserves data in this press release is based upon an evaluation by
Netherland, Sewell & Associates, Inc. (“NSAI”) with an effective date of
December 31, 2016. The reserves data summarizes PetroShale’s crude oil and
natural gas reserves and the net present value of future net revenue for these
reserves using forecast prices and costs. All references to reserves are to
gross Company reserves, meaning PetroShale’s working interest reserves before
consideration of royalty interests. The reserve report has been prepared in
accordance with the standards contained in the COGE Handbook and the reserve
definitions contained in National Instrument 51-101 (“NI 51-101”) and CSA Staff
Notice 51-324. No attempt was made to evaluate possible reserves.

Reserves Highlights:

/T/

— P+P reserves increased 23% to 31,450 Mboe, compared to 25,483 Mboe as at

December 31, 2015;
— Proved developed producing reserves increased by 45% to 5,238 Mboe, and
total proved reserves increased by 29% to 25,134 Mboe;
— Before tax NPV10 of the Company’s P+P reserves increased by 29% to
US$399.5 million, while the NPV10 of total proved reserves increased 34%
to US$333.4 million;
— P+P finding, development and acquisition costs (“FD&A”) were $9.17 per
boe for 2016 (year ended December 31, 2015 – $9.69) (including changes
in future development capital) reflecting a strong recycle ratio of 2.7
times based on our Q4 2016 operating netback (2.2 times based on 2016
average netback); while total proved FD&A was $10.89 per boe (year ended
December 31, 2015 – $9.88) with a recycle ratio of 2.2 times based on
our Q4 2016 operating netback (1.9 times based on 2016 average netback);
— P+P finding and development costs (“F&D”) were $16.69 per boe for 2016
(year ended December 31, 2015 – $14.21) (including changes in future
development capital) and total proved F&D was $17.37 per boe (year ended
December 31, 2015 – $14.94); and
— P+P Reserve Life Index is 46.3 years, reflecting Q4 2016 average
production of 1,861 boe per day.

/T/

Gross Company Interest Reserves

/T/

Reserves
—————————————————–
Tight Oil Shale Gas(2) BOE
—————————————————–
Gross Net Gross Net Gross Net
Reserves Category (Mbbl) (Mbbl) (Mmcf) (Mmcf) (Mboe) (Mboe)
—————————————————–
PROVED:
Developed Producing 4,143.0 3,284.4 6,570.4 5,188.2 5,238.1 4,149.1
Developed Non-
Producing 58.6 46.1 5.5 4.3 59.5 46.8
Undeveloped 16,707.4 13,270.5 18,773.7 14,908.0 19,836.4 15,755.2
—————————————————————————-
TOTAL PROVED 20,909.1 16,601.0 25,349.6 20,100.4 25,134.0 19,951.1
PROBABLE 5,340.6 4,239.2 5,854.4 4,644.2 6,316.3 5,013.2
—————————————————————————-
TOTAL PROVED PLUS
PROBABLE 26,249.6 20,840.2 31,204.0 24,744.6 31,450.3 24,964.3
—————————————————————————-
Notes:
(1) Columns may not add due to rounding.
(2) All of our shale gas reserves represent solution gas associated with our
tight oil reserves.

/T/

Net Present Value of Future Net Revenue ($ US)

/T/

Before Income Taxes Discounted at (%/year)
————————————————-
0% 5% 10% 15% 20%
($US ($US ($US ($US ($US
Reserves Category 000s) 000s) 000s) 000s) 000s)
————————————————-
PROVED:
Developed Producing 161,655.6 115,408.1 90,270.2 74,902.9 64,639.1
Developed Non-Producing 1,277.9 972.7 767.7 626.3 525.5
Undeveloped 586,079.5 360,960.0 242,321.5 171,908.4 126,431.7
—————————————————————————-
TOTAL PROVED 749,013.0 477,340.8 333,359.4 247,437.6 191,596.3
PROBABLE 169,611.6 102,436.2 66,163.4 44,665.8 31,012.0
—————————————————————————-
TOTAL PROVED PLUS PROBABLE 918,624.7 579,777.0 399,522.8 292,103.4 222,608.3
—————————————————————————-
Notes:
(1) Columns may not add due to rounding

/T/

As a reporting issuer in Canada, PetroShale is required to report its reserves
and NPV10 using forecast pricing and costs, as stipulated under NI 51-101. The
forecast prices reflected in the NPV10 is included in its year end 2016 Annual
Information Form filed on SEDAR.

Reserves Reconciliation

/T/

Total (Mboe)
———————————–
Total
Total Proved Plus
Proved Probable Probable
———————————–
December 31, 2015 19,453.6 6,029.2 25,482.9
Discoveries – – –
Extensions and Improved Recovery – – –
Technical Revisions (1) 3,971.1 (340.2) 3,630.9
Acquisitions (2) 2,972.5 680.6 3,653.1
Dispositions (180.2) (43.5) (223.7)
Economic Factors (488.3) (9.8) (498.1)
Production (3) (594.8) – (594.8)
—————————————————————————-
December 31, 2016 25,134.0 6,316.3 31,450.3
—————————————————————————-
Notes:
(1) Technical revisions include additional well locations assigned proved
undeveloped and probable reserves as well as increased proved and probable
reserve assignments to well locations included in the December 31, 2015
reserve report. These revisions are based on additional technical
information gathered in 2016 from analogous wells drilled and completed
near our lands and increases in the number of wells planned by operators on
our lands.
(2) The acquisitions amount is the estimate of reserves at December 31,
2016.
(3) Columns may not add due to rounding.

/T/

2016 Capital Program Efficiency

/T/

Finding, Development & Finding & Development
Acquisition (“FD&A”)(1) (“F&D”)(1)
———————————————–
Total Proved plus Total Proved plus
Proved Probable Proved Probable
———————————————–
Capital Costs ($000s):
Acquisitions 8,505 8,505
Dispositions (651) (651)
Capital expenditures 20,909 20,909 20,909 20,909
Change in future
development capital 39,593 31,399 39,593 31,399
—————————————————————————-
Total FD&A / F&D Costs 68,356 60,162 60,502 52,308
—————————————————————————-
—————————————————————————-

Reserves additions (Mboe)

Net change in reserve
volumes 5,680 5,968 5,680 5,968
Add back production 595 595 595 595
Reserves associated with
acquisitions – – (2,973) (3,653)
Reserves associated with
dispositions – – 180 224
—————————————————————————-
Total additions 6,275 6,563 3,483 3,134
—————————————————————————-
—————————————————————————-
FD&A and F&D Costs ($/boe) $ 10.89 $ 9.17 $ 17.37 $ 16.69
Recycle Ratio(2) 2.2 2.7 1.4 1.5
—————————————————————————-
—————————————————————————-
Notes:
(1) The calculation of F&D and FD&A costs incorporates the change in future
development capital (“FDC”) required to bring proved undeveloped and
probable reserves into production. In all cases, the F&D or FD&A number is
calculated by dividing the identified capital expenditures, after changes
in FDC, by the applicable reserves additions. We have disclosed both
finding and development costs and finding, development and acquisition
costs because acquisition costs have been a significant component of our
total capital expenditures and strategy, and also due to the difficulty in
allocating changes in future development costs between reserve additions
from drilling, technical revisions and acquisitions. For purposes of
calculating finding and development costs, we have chosen to include the
full increase in future development costs in this measure, rather than
allocating only a portion of it to finding and development costs as such an
allocation would be complex, and the method we have chosen is conservative.
(2) Recycle ratio is defined as operating netback, for the fourth quarter of
2016, divided by F&D or FD&A costs, as applicable, on a per boe basis.
Operating netback is calculated as revenue (including realized hedging
gains and losses) minus royalties, operating costs and production taxes.
PetroShale’s operating netback in Q4 2016 averaged $24.35 per boe.

Pro-Forma
Net Asset Value (“NAV”) per Share as at December 31, Equity
2016 Financing
———————–
($ thousands, except share and per share amounts)

Proved Plus Probable Reserve Value (NPV10 Before
Tax) $ 535,361 $ 535,361
Net Debt (including Decommissioning Obligation) (149,369) (43,169)
—————————————————————————-
Total Net Assets $ 385,992 $ 492,192
Common Shares Outstanding 34,207,574 156,472,574
—————————————————————————-
Estimated Net Asset Value per Diluted Common
Share2 $ 10.01 $ 3.08
—————————————————————————-
Notes:
(1) Net asset value is calculated as at a particular date and is, by its
nature, historical, and may not be reflective of PetroShale’s future
performance. Reflects the NPV10 of the Company’s reserves at an exchange
rate of US$1.00 = Cdn$1.34.
(2) Reflects the dilutive impact of 2.0 million share purchase warrants
exercisable at $0.75 per share and 2,736,736 share purchase options with an
average exercise price of $0.83 per share, outstanding as at this date.

/T/

MESSAGE FROM THE CEO

2016 represented another year of growth and milestones achieved at PetroShale.
We drilled and completed our first well (73% working interest) in the Antelope
area which moved PetroShale from a non-operating, working interest owner to an
operator in the prolific Williston Basin. Our operated position in this
particular drilling unit was built through several transactions over the past
few years, and we believe the opportunity exists to consolidate interests to an
operated position in other drilling units in our core focus area. Earlier in
December, we participated in three non-operated wells in which we have a 24.7%
working interest. We are very pleased with and encouraged by the results from
our first operated well, as well as the production impact from the three
non-operated wells, and believe PetroShale is positioned to achieve significant
longer-term increases in production, reserves and revenue growth.

PetroShale’s current production is approximately 2,800 boe per day, an increase
of 50% from our fourth quarter average.

We further strengthened our financial position with an equity offering of
122,265,000 common shares at $0.90 per share that closed on April 11, 2017, and
generated net proceeds of approximately $106 million. As a result of this
financing, we currently have approximately US$79 million of undrawn capacity
under our credit facilities.

The quality of our asset base and the strength of our strategy is clearly
demonstrated by PetroShale’s fourth quarter 2016 operating netback of $24.35
per boe ($30.86 per boe on a net of royalty basis), which highlights our
ability to generate compelling economics during a period of moderate oil price
levels. We expect to see improved differentials between WTI and Bakken crude
prices in 2017 due to the commencement of operations of the Dakota Access
Pipeline, which significantly enhances takeaway capacity from the Bakken to the
Gulf Coast and other markets.

Our year end 2016 reserves evaluation reflected another year of increased
reserves volumes and value across all categories as a result of our ongoing
active development and acquisition activity. Our P+P reserves increased to 31.5
million boe, from 25.5 million boe at December 31, 2015, representing growth of
23%. The NPV10 of our P+P reserves increased to US$399.5 million, a 29%
increase over US$308.7 million last year. We achieved this growth responsibly,
with P+P FD&A costs averaging $9.17 per boe (including the change in future
development capital), generating an attractive P+P recycle ratio of 2.7 times.
These capital efficiencies provide further evidence of the quality of our land
base.

PetroShale’s enhanced liquidity from the increase and extension of our senior
credit facility and completion of the equity offering will enable the Company
to carry out our 2017 business plan. We continue to seek opportunities to
enhance our high-quality asset base within or adjacent to our core areas and
look forward to further results as we continue to drill and develop our
operated DSU.

We would like to thank PetroShale’s employees, directors and shareholders for
your continued support of our strategy and our Company, and we look forward to
updating you on our progress and achievements during 2017.

((signed))

M. Bruce Chernoff
Executive Chairman and CEO

About PetroShale

PetroShale is an oil company engaged in the acquisition, development and
consolidation of interests in the North Dakota Bakken / Three Forks.

Note Regarding Forward-Looking Statements and Other Advisories

This press release contains forward-looking statements and forward-looking
information (collectively “forward-looking information”) within the meaning of
applicable securities laws relating to, among other things, available aspects
of management focus, objectives, strategies and business opportunities. More
particularly and without limitation, this press release contains
forward-looking information concerning: the opportunity to use available and
undrawn amounts under the Company’s credit facilities to fund drilling and
acquisitions, PetroShale’s position to achieve future growth in production,
reserves and revenue; PetroShale’s intention to seek out land acquisition
opportunities; the sufficiency of the Company’s financial flexibility and
capital requirements; the Company’s growth and development plans; the Company’s
participation in drilling opportunities and the future prospects for new wells;
and the general outlook of the Company. PetroShale provided such
forward-looking statements in reliance on certain expectations and assumptions
that it believes are reasonable at the time, including expectations and
assumptions concerning prevailing commodity prices, liquidity, exchange rates,
interest rates, applicable royalty rates and tax laws; future production rates
and estimates of operating costs; performance of existing and future wells;
reserve volumes; business prospects and opportunities; the availability and
cost of financing, labor and services; the impact of increasing competition;
ability to market oil and natural gas successfully; and the Company’s ability
to access capital.

Statements relating to “reserves” are also deemed to be forward looking
statements, as they involve the implied assessment, based on certain estimates
and assumptions, that the reserves described exist in the quantities predicted
or estimated and that the reserves can be profitably produced in the future.

Although the Company believes that the expectations and assumptions on which
such forward-looking information is based are reasonable, undue reliance should
not be placed on the forward-looking information because the Company can give
no assurance that they will prove to be correct. Forward-looking information
addresses future events and conditions, which by their very nature involve
inherent risks and uncertainties. The Company’s actual results, performance or
achievement could differ materially from those expressed in, or implied by, the
forward-looking information and, accordingly, no assurance can be given that
any of the events anticipated by the forward-looking information will transpire
or occur, or if any of them do so, what benefits the Company will derive
therefrom. Management has included the above summary of assumptions and risks
related to forward-looking information provided in this press release in order
to provide security holders with a more complete perspective on the Company’s
future operations and such information may not be appropriate for other
purposes.

Readers are cautioned that the foregoing lists of factors are not exhaustive.
Additional information on these and other factors that could affect our
operations or financial results are included in reports on file with applicable
securities regulatory authorities and may be accessed through the SEDAR website
(www.sedar.com). These forward-looking statements are made as of the date of
this press release and the Company disclaims any intent or obligation to update
publicly any forward-looking information, whether as a result of new
information, future events or results or otherwise, other than as required by
applicable securities laws.

Non-GAAP Measures:

Within this press release, references are made to “NAV”, “operating netback”
and “EBITDA”, which are not recognized measures under IFRS and therefore may
not be comparable to performance measures presented by others. EBITDA means net
income (loss) before taxes, depletion and depreciation expense, exploration and
evaluation expense, any impairments, finance expense, any gain or loss on
property dispositions, foreign exchange gain or loss, share-based compensation
expense and unrealized gain or loss on financial derivatives. Operating netback
means revenue less royalties, production taxes and operating costs and has been
presented on a per Boe basis. NAV means net asset value, which is the NPV10
before tax of the Company’s proved plus probable reserves, less net debt.
Management believes that in addition to net income (loss) and cash flow from
(used in) operating activities, EBITDA and operating netback are useful
supplemental measures as they assist a reader in the determination of the
Company’s operating performance, leverage and liquidity. Management believes
NAV or net asset value is a useful measure as it assists the reader in
determining the Company’s value per share. Readers are cautioned, however, that
these measures should not be construed as an alternative to net income (loss)
or cash flow from (used in) operating activities and consolidated assets as
determined in accordance with IFRS as an indication of our performance or value.

Oil and Gas Advisories:

This press release contains certain oil and gas metrics such as “finding and
development costs” (or F&D), “finding development and acquisition costs” (or
FD&A), “Recycle Ratio”, and “Reserve Life Index”, which do not have
standardized meanings or standard methods of calculation and therefore such
measures may not be comparable to similar measures used by other companies and
should not be used to make comparisons. Such metrics have been included in this
document to provide readers with additional measures to evaluate the
performance of our oil and gas activities however, such measures are not
reliable indicators of our future performance and future performance may not
compare to our performance in previous periods and therefore such metrics
should not be unduly relied upon. We have disclosed both finding and
development costs and finding, development and acquisition costs as measures in
this press release because acquisition costs have been a significant component
of our total capital expenditures and strategy, and also due to the difficulty
in allocating changes in future development costs between reserve additions
from drilling, technical revisions and acquisitions. For purposes of
calculating finding and development costs, we have chosen to include the full
increase in future development costs in this measure, rather than allocating
only a portion of it to finding and development costs as such an allocation
would be complex, and the method we have chosen is conservative. We believe
both measures are useful measures for readers to determine the efficiency of
our acquisition and development program. Recycle Ratio is defined as operating
netback divided by F&D or FD&A costs, as applicable, on a per boe basis.
Management uses this measure as an indicator of profitability of its oil and
gas activities. Reserves Life Index is calculated as total company share
reserves divided by annual production. Management uses this measure to
determine how long the booked reserves will last at current production rates if
no further reserves were added.

Where amounts are expressed on a barrel of oil equivalent (“Boe”) basis,
natural gas volumes have been converted to Boe using a ratio of 6,000 cubic
feet of natural gas to one barrel of oil (6 Mcf: 1 Bbl). This Boe conversion
ratio is based on an energy equivalency conversion method primarily applicable
at the burner tip and does not represent a value equivalency at the wellhead.
Given the value ratio based on the current price of crude oil as compared to
natural gas is significantly different from the energy equivalency of 6 Mcf: 1
Bbl, utilizing a conversion ratio at 6 Mcf: 1 Bbl may be misleading as an
indication of value. In this release, mboe refers to thousands of barrels of
oil equivalent, while mbbls refers to thousands of barrels of oil, and mmcf
refers to millions of cubic feet of natural gas.

All dollar figures included herein are presented in Canadian dollars, unless
otherwise noted.

– END RELEASE – 28/04/2017

For further information:
PetroShale Inc.
Attention: Executive Chairman and CEO
Email: Info@PetroShaleInc.com
Phone: +1.303.297.1407
www.petroshaleinc.com
OR
Cindy Gray
5 Quarters Investor Relations, Inc.
403.828.0146 or info@5qir.com

COMPANY:
FOR: PETROSHALE INC.
TSX VENTURE SYMBOL: PSH
OTCQX SYMBOL: PSHIF

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170428CC0027

Press Release from Marketwired 1-866-736-3779

VIQ Solutions Reports Fourth Quarter and Full Year 2016 Results

April 28, 2017 by The Canadian Press

FOR: VIQ SOLUTIONS INC.TSX VENTURE SYMBOL: VQSDate issue: April 28, 2017Time in: 8:00 AM eAttention:
MARKHAM, ONTARIO–(Marketwired – April 28, 2017) – VIQ Solutions Inc. (“VIQ
Solutions” or the “Company”) (TSX VENTURE:VQS), a global expert in secure
…

Enbridge Inc. Announces Conclusion and Outcomes of Enbridge Energy Partners, L.P. Strategic Review

April 28, 2017 by The Canadian Press

FOR: ENBRIDGE INC.
TSX SYMBOL: ENB
NYSE SYMBOL: ENB

Date issue: April 28, 2017
Time in: 7:00 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 28, 2017) – Enbridge Inc.
(TSX:ENB)(NYSE:ENB) (Enbridge or the Company) announced today that the
strategic review of Enbridge Energy Partners, L.P. (NYSE:EEP) (EEP or the
Partnership) has been completed. The following actions, together with the
previously announced measures earlier this year, have been taken to restore
EEP’s value proposition to its unitholders and to Enbridge.

Acquisition of Midcoast Assets – Enbridge, through its wholly owned U.S.
subsidiary Enbridge Energy Company, Inc. (EECI), will acquire EEP’s interest in
the Midcoast Gas Gathering & Processing business (Midcoast) for cash
consideration of US$1.31 billion plus existing indebtedness of Midcoast Energy
Partners, L.P. (MEP) (which was US$840 million as at March 31, 2017).
Subsequent to the closing of the previously announced privatization of MEP,
which closed on April 27, 2017, 100 percent of the Midcoast business will be
owned by EECI.

Finalization of Bakken Pipeline System Joint Funding Agreement (JFA) – EECI and
EEP finalized a JFA whereby the investment will be jointly owned 75 percent by
EECI and 25 percent by EEP. The Bakken Pipeline System is expected to be placed
into service during the second quarter of 2017 and is expected to generate
strong and stable cash flows for both Enbridge and EEP.

EEP Redemption of Series 1 Preferred Units – EEP will redeem and repay US$1.6
billion of obligations related to its Series 1 Preferred Units outstanding to
EECI, including US$357 million of accumulated deferred distributions. EEP will
fund the US$1.2 billion face value of the preferred units by issuing US$1.2
billion of Class A common units to EECI, and repay the deferred distributions
with a portion of the cash proceeds from the sale of the Midcoast assets. This
transaction simplifies EEP’s capital structure and improves its credit profile.

In addition to the foregoing, the Board of the Partnership’s designate manager
announced a reduction in EEP’s quarterly distribution from US$0.583 to US$0.350
per unit to unitholders of record at the close of business on May 8,, 2017.
Retaining additional cash flow allows EEP to internally fund more of its
attractive growth projects, alleviate near term equity capital requirements and
strengthen its balance sheet.

“EEP holds some of our most strategic and high quality, long-life, critical
energy infrastructure assets in North America,” said Al Monaco, President and
CEO of Enbridge. “The objective of the strategic review was to re-establish EEP
as an effective sponsored vehicle for the benefit of EEP unitholders and
Enbridge. We believe today’s actions, and those undertaken earlier this year,
achieve this objective by returning EEP to a pure-play liquids pipeline MLP –
with premium low-risk assets, a strong financial position, self-funding
capability, ample distribution coverage and visible growth. Both EEP
unitholders and Enbridge shareholders will continue to derive value from these
unique assets in the near term and in the years to come.”

On January 27, EEP and Enbridge announced interim measures to alleviate EEP’s
near-term funding requirements and enhance its cash flows, including the
acquisition by Enbridge of the public float in MEP, the finalization of a joint
funding arrangement for the U.S. portion of the Line 3 Replacement Project
(L3R), and the exercise of EEP’s option for an additional 15 percent interest
in the cash generating Eastern Access Project. Those initiatives, together with
those announced today, reposition EEP as a compelling low-risk investment. The
transactions result in a more streamlined capital structure at EEP and simplify
Enbridge’s holdings in the Partnership by eliminating certain classes of
preferred and partnership units. There are no other material support actions by
Enbridge required, nor are any further actions contemplated.

The combined restructuring actions have the overall effect of Enbridge
acquiring all of EEP’s gas gathering and processing business and a 99 percent
interest in L3R in exchange for approximately US$1.1 billion in net cash and
the transfer to EEP of a 15 percent interest in the Eastern Access Expansion.
EEP will initially hold a 25 percent interest in the Bakken System Pipeline
investment and an initial 1 percent interest in L3R with options to increase
its ownership in these two strong projects by 20 percent and 39 percent,
respectively. Together with a third existing option, a 15 percent interest in
the Mainline Expansion project, EEP will hold options for a total capital
investment opportunity of US$1.6 billion. Enbridge will realize reduced
distributions from EEP as a result of EEP’s reduction in unitholder
distributions.

Enbridge Sponsored Vehicle Strategy

With regard to Enbridge’s overall sponsored vehicle strategy, Mr. Monaco added:
“We believe that sponsored vehicles can be an effective way to hold and grow
energy infrastructure assets and they can provide a good source of funding that
can optimize the overall cost of capital for the Enbridge group, much like they
have done for us over time.”

“That said, removing unnecessary complexity from our business has always been a
priority for Enbridge where it makes sense. Since the beginning of the year,
our structure has been streamlined by privatizing MEP, consolidating DCP
Midstream L.P. (DCP) and restoring EEP’s value proposition. This leaves us with
two strong pure-play pipeline MLPs: one being a liquids pipeline business (EEP)
and the other a natural gas pipeline business (Spectra Energy Partners, L.P.
(SEP) – NYSE:SEP). We also have an interest in DCP – a pure-play premier gas
gathering and processing business, which is now also well positioned within its
sector. There are no plans for other major changes; however, we will review our
structure on an on-going basis with a view to rationalizing our holdings to
maximize transparency and shareholder value.”

SEP will be maintained as a long-haul natural gas pipeline business with a
continuation of its compelling investor value proposition. There is no plan or
intention to transfer the Midcoast assets to SEP.

All of the strategic review actions are scheduled to close by the end of the
first half of this year and are not expected to be material. Enbridge will be
providing its first quarterly financial results post the Spectra transaction
along with its combined 2017 financial outlook on May 11.

FORWARD-LOOKING INFORMATION

Certain information provided in this news release constitutes forward-looking
statements. The words “anticipate”, “expect”, “project”, “estimate”,
“forecast”, “plan”, “intend”, “believe” and similar expressions are intended to
identify such forward-looking statements. Forward-looking statements in this
news release include, but are not limited to, statements with respect to: the
strategic review of EEP and the transactions or other actions arising from such
review, including with regards to the timing and closing of such transactions
and the anticipated benefits and efficiencies to be derived therefrom; the
Company’s funding of its investment in EEP and MEP; the financing arrangements
between the Company, EECI, EEP and MEP ; longer-term funding options and other
future support actions; project in service dates and cash flow projections; the
Company’s financial outlook and projections; and the Company’s overall
sponsored vehicle strategy, including with regards to any future review or
changes of the sponsored vehicle structure or any transactions involving the
sponsored vehicles. Although the Company believes these statements are based on
information and assumptions which are current, reasonable and complete, these
statements are necessarily subject to a variety of assumptions, risks and
uncertainties pertaining to the terms, timing and completion of the proposed
transactions and strategic review and the realization of anticipated benefits
and efficiencies; interim financing and longer-term funding, including
definitive terms thereof; operating performance; future business prospects and
performance; financial strength and flexibility; debt and equity market
conditions; regulatory parameters; customer, shareholder, regulatory and other
stakeholder approvals and support; anticipated in service dates; economic and
competitive conditions; exchange rates, inflation and interest rates; changes
in tax law and tax rates; counterparty risk; the availability and price of
labour and construction materials; and supply of and demand for commodities and
commodity prices. A further discussion of the risks and uncertainties facing
the Company can be found in the Company’s filings with Canadian and United
States securities regulators. While the Company makes these forward-looking
statements in good faith, should one or more of these risks or uncertainties
materialize, or should underlying assumptions prove incorrect, actual results
may vary significantly from those expected. Except as may be required by
applicable securities laws, the Company assumes no obligation to publicly
update or revise any forward-looking statements made herein or otherwise,
whether as a result of new information, future events or otherwise.

About Enbridge Inc.

Enbridge Inc. is North America’s premier energy infrastructure company with
strategic business platforms that include an extensive network of crude oil,
liquids and natural gas pipelines, regulated natural gas distribution utilities
and renewable power generation. The Company safely delivers an average of 2.8
million barrels of crude oil each day through its Mainline and Express
Pipeline, and accounts for nearly 68% of U.S.-bound Canadian crude oil
production, and moves approximately 20% of all natural gas consumed in the U.S.
serving key supply basins and demand markets. The Company’s regulated utilities
serve approximately 3.5 million retail customers in Ontario, Quebec, New
Brunswick and New York State. Enbridge also has a growing involvement in
electricity infrastructure with interests in more than 2,500 MW of net
renewable generating capacity, and an expanding offshore wind portfolio in
Europe. The Company has ranked on the Global 100 Most Sustainable Corporations
index for the past eight years; its common shares trade on the Toronto and New
York stock exchanges under the symbol ENB.

Life takes energy and Enbridge exists to fuel people’s quality of life. For
more information, visit www.enbridge.com.

– END RELEASE – 28/04/2017

For further information:
Enbridge Inc.
Media
Suzanne Wilton
(403) 231-7385 or Toll Free: (888) 992-0997
suzanne.wilton@enbridge.com
OR
Enbridge Inc.
Investment Community
Jonathan Gould
(403) 231-3916 or Toll Free: (800) 481-2804
investor.relations@enbridge.com

COMPANY:
FOR: ENBRIDGE INC.
TSX SYMBOL: ENB
NYSE SYMBOL: ENB

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170428CC0014

Press Release from Marketwired 1-866-736-3779

Gran Tierra Announces Release Date for its 2017 First Quarter Results, Conference Call and Webcast Details

April 28, 2017 by The Canadian Press

FOR: GRAN TIERRA ENERGY INC.
TSX SYMBOL: GTE
NYSE MKT SYMBOL: GTE

Date issue: April 28, 2017
Time in: 6:00 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 28, 2017) – Gran Tierra Energy Inc.
(“Gran Tierra”) (NYSE MKT:GTE)(TSX:GTE), announces that the Company will
release its 2017 first quarter financial results on Wednesday, May 3, 2017
after markets close. A conference call to discuss the 2017 first quarter
results will be held at 11:00 a.m. Eastern Time (9:00 a.m. Mountain Time) on
Thursday, May 4, 2017. Details of the conference call are as follows:

/T/

—————————————————————————-
Date: Thursday, May 4, 2017
—————————————————————————-
Time: 11:00 a.m. Eastern Time (9:00 a.m.
Mountain Time)
—————————————————————————-
North American participants call: 1-844-348-3792 (Toll-Free)
—————————————————————————-
Outside of Canada & USA call: 1-614-999-9309
—————————————————————————-

/T/

Interested parties may also access the live webcast on the investor relations
page of Gran Tierra’s website at www.grantierra.com. An archive of the webcast
will be available on Gran Tierra’s website until the next earnings call. In
addition, an audio replay of the conference call will be available following
the call until May 11, 2017. To access the replay, dial toll-free
1-855-859-2056 (North America), or 1-404-537-3406 (outside of Canada and USA),
Conference ID: 9267216.

About Gran Tierra Energy Inc.

Gran Tierra Energy Inc. together with its subsidiaries is an independent
international energy company focused on oil and natural gas exploration and
production in Colombia. The Company also has business activities in Peru and
Brazil.

Gran Tierra’s Securities and Exchange Commission filings are available on a web
site maintained by the Securities and Exchange Commission at http://www.sec.gov
and on SEDAR at http://www.sedar.com.

– END RELEASE – 28/04/2017

For further information:
For investor and media inquiries please contact:
Gary Guidry
Chief Executive Officer
403-767-6500
OR
Ryan Ellson
Chief Financial Officer
403-767-6501
OR
Rodger Trimble
Vice President, Investor Relations
403-698-7941
info@grantierra.com
www.grantierra.com

COMPANY:
FOR: GRAN TIERRA ENERGY INC.
TSX SYMBOL: GTE
NYSE MKT SYMBOL: GTE

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170428CC0004

Press Release from Marketwired 1-866-736-3779

Job Opportunities Poised for Growth in the Emerging Canadian Methane Services Industry, According to New Market Survey

April 27, 2017 by The Canadian Press

FOR: METHANE EMISSION LEADERSHIP ALLIANCE
Date issue: April 28, 2017Time in: 12:01 AM eAttention:
CALGARY, AB –(Marketwired – April 28, 2017) – An analysis by the Methane
Emissions Leadership Alliance (MELA), an industry association of Canadian
meth…

Industry group raises oil and gas drilling forecast again on price stability

April 27, 2017 by The Canadian Press

CALGARY — An oil and gas industry group is once again raising its drilling forecast for the year after seeing higher than expected activity.

The Petroleum Services Association of Canada now expects 6,680 wells to be drilled across Canada in 2017, up about 60 per cent from what it had forecast in November.

Association president Mark Salkeld said the stability of oil prices and lower costs are helping raise the expected number of wells.

He said the biggest barriers to further growth for the industry are the need for pipelines to tidewater and liquid natural gas projects.

Alberta saw the highest jump in the forecast update, with the expected number of wells rising about 75 per cent to 3,320 for the year.

Saskatchewan is expected to see 2,670 wells, British Columbia 449 wells and Manitoba 221 wells.

The Canadian Press

PSAC Raises Its 2017 Drilling Activity Forecast: Strong first quarter leads to an upward revision of over 2,500 wells for 2017

June 28, 2017April 27, 2017 by EnergyNow Media

Calgary, Alberta – Today, the Petroleum Services Association of Canada (PSAC), in its second update to the 2017 Canadian Drilling Activity Forecast, announced its revision of the forecasted number of wells drilled (rig released) across Canada for 2017 to 6,680 wells. This represents an increase of 2,505 wells and a 60 per cent increase from … Read more

Colorado: No sign yet of well leak in fatal home explosion

April 27, 2017April 27, 2017 by The Canadian Press

DENVER — Colorado regulators say they’ve found no signs of natural gas leaks after a fatal explosion at a home near a gas well, but they’re still running tests.

State Oil and Gas Conservation Commission Director Matt Lepore said Thursday air sampling after the explosion found no trace of escaped gas in the neighbourhood. Soil samples are planned.

Lepore says he doesn’t believe the public is in immediate danger.

Two people died when the house exploded April 17 in Firestone, 30 miles (48 kilometres) north of Denver. The house was within 200 feet (60 metres) of a well producing mostly gas and some oil.

Lepore and fire officials say they don’t know what caused the explosion but the well is part of the investigation.

That well and others have been shut down.

The Associated Press

Inventronics Announces 2016 Annual and 2016 Q4 Financial Results; and 2017 Q1 Financial Results

April 27, 2017 by The Canadian Press

FOR: INVENTRONICS LIMITED
TSX VENTURE SYMBOL: IVX

Date issue: April 27, 2017
Time in: 7:17 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 27, 2017) – Inventronics Limited
(“Inventronics” or the “Corporation”) (TSX VENTURE:IVX), a designer and
manufacturer of custom enclosures for the telecommunications, electric
transmission, cable television and other industries in North America, today
announced its audited 2016 annual and 2016 Q4 financial results and its
unaudited 2017 Q1 financial results.

2016 Annual and 2016 Q4

For the year ended December 31, 2016, Inventronics reported a net loss of
$283,000, or 6.4 cents per share, on revenue of $3,830,000 compared to a net
loss of $414,000, or 9.4 cents per share, on revenue of $4,187,000 for the 2015
fiscal year.

For the three months ended December 31, 2016, Inventronics reported a net loss
of $46,000, or 1.1 cents per share, on revenue of $1,009,000 compared to a net
loss of $230,000, or 5.2 cents per share, on revenue of $822,000, for the three
months ended December 31, 2015.

2017 Q1

For the three months ended March 31, 2017, Inventronics reported a net loss of
$34,000, or 0.8 cents per share, on revenue of $1,008,000 compared to a net
loss of $208,000, or 4.7 cents per share, on revenue of $760,000 for the three
months ended March 31, 2016.

Selected Financial Information

/T/

Three Months Twelve Months Three Months
Income Highlights Ended Ended Ended
(in thousands of
dollars, except per Dec 31 Dec 31 Dec 31 Dec 31 Mar 31 Mar 31
share amounts) 2016 2015 2016 2015 2017 2016
—————————————————————————-
Revenue 1,009 822 3,830 4,187 1,008 760
EBITDA 76 (108) 213 82 87 (83)
Net loss (46) (230) (283) (414) (34) (208)
Basic loss per share (1.1) (5.2) (6.4) (9.4) (0.8) (4.7)
cents cents cents cents cents cents

/T/

Statement of Financial Position Highlights

/T/

December December
(in thousands of dollars) 31 31 March 31
As at 2016 2015 2017
—————————————————————————-
Working capital 303 317 327
Property, plant and equipment 2,234 2,538 2,166
Long-term debt, excluding current portion 2,234 2,270 2,224
Shareholders’ equity 329 612 295

/T/

Further information about the financial results of the Corporation can be found
in the Corporation’s audited annual financial statements for the year ended
December 31, 2016 and accompanying management’s discussion and analysis (“2016
Annual MD&A”) and the Corporation’s unaudited interim financial statements for
the quarter ended March 31, 2017 and accompanying management’s discussion and
analysis (“2017 Q1 MD&A”) which have been filed on SEDAR at www.sedar.com.

About Inventronics

Inventronics Limited designs and manufactures custom enclosures and other
products for an array of customers in the telecommunications, electric utility,
cable television, oil and gas, electronics and computer services industries in
North America. The Corporation owns its ISO 9001-registered production facility
in Brandon, Manitoba.

Shares of Inventronics trade on the TSX Venture Exchange under the symbol
“IVX.” For more information about the Corporation, its products and its
services, go to www.inventronics.com.

Non-IFRS Measures

Earnings before interest, tax, depreciation and amortization (“EBITDA”), as
presented in this press release, is not a recognized measure under
International Financial Reporting Standards (“IFRS”). However, management
believes that EBITDA is a useful supplementary measure to net earnings, as it
provides investors with an indication of cash earnings prior to debt service,
capital expenditure, income tax and non-cash items. Readers should be
cautioned, however, that EBITDA should not be construed as an alternative to
net earnings determined in accordance with IFRS as an indicator of the
Corporation’s performance or to cash flows from operating, investing and
financing activities as a measure of liquidity or cash flows. The Corporation’s
method of calculating EBITDA may differ from the methods by which other
companies calculate EBITDA and, accordingly, the EBITDA used herein may not be
comparable to measures used by other companies. For further information
relating to how the Corporation calculates EBITDA, including a reconciliation
of EBITDA to net earnings, please see the 2016 Annual MD&A and the 2017 Q1 MD&A.

Neither TSX Venture Exchange nor its Regulation Services Provider (as that term
is defined in policies of the TSX Venture Exchange) accepts responsibility for
the adequacy or accuracy of this release.

– END RELEASE – 27/04/2017

For further information:
Inventronics Limited
Dan J. Stearne
President and CEO
(204) 728-2001 ext. 145
dstearne@inventronics.com

COMPANY:
FOR: INVENTRONICS LIMITED
TSX VENTURE SYMBOL: IVX

INDUSTRY: Electronics and Semiconductors – Electronic Design
Architecture, Telecom – Telecommunication Equipment
RELEASE ID: 20170427CC0102

Press Release from Marketwired 1-866-736-3779

Exxon fined $20 million for emissions from Texas plant

April 27, 2017 by The Canadian Press

BAYTOWN, Texas — A judge has ordered Exxon Mobil to pay a penalty of nearly $20 million for releasing 10 million pounds of pollutants into the air over the course of eight years from a refining and chemical complex east of Houston.

U.S. District Judge David Hittner in a ruling Wednesday determined that Texas-based Exxon on thousands of occasions from 2005 to 2013 violated federal clean-air standards.

The Houston Chronicle reports (http://bit.ly/2oMZ7Lr ) the finding is the result of a lawsuit filed in 2010 by two environmental groups.

The groups argued Exxon collected more than $14 million in economic benefits by delaying measures to curb the emissions from its plant in Baytown. They contend the pollution could have been detected earlier using improvements such as infrared imaging technology.

Exxon says it’s considering an appeal.

The Associated Press

Justin Trudeau defends carbon tax after visit to Saskatchewan farm

April 28, 2017April 27, 2017 by The Canadian Press

GRAY, Sask. — Prime Minister Justin Trudeau appears to like farmer Todd Lewis’s combine, but Lewis does not like Trudeau’s carbon tax.

Trudeau happily hopped into a combine during a visit Thursday to the Lewis family’s century-old farm in the community of Gray, south of Regina.

“Glad to see how you guys have developed some amazing ways to succeed,” Trudeau said.

He climbed into a sprayer too, and was told how it uses a GPS so that the nozzles automatically turn off if they overlap to save fertilizer and fuel costs.

Most of the farm technology has been developed in Saskatchewan and Western Canada, Lewis told him.

“A real point of pride for all of Canada,” replied Trudeau.

And that’s the recognition Lewis wants for farmers when it comes to Trudeau’s carbon tax.

Trudeau has said all provinces must set up a cap-and-trade system or impose a price on carbon of at least $10 per tonne starting next year, increasing to $50 by 2022.

“Putting a price on carbon pollution is a way of encouraging and rewarding people who are innovating and reducing their carbon pollution outputs,” the prime minister said at a news conference in front of a couple hundred people at the Gray rink.

Trudeau said every penny collected from a carbon tax in Saskatchewan will stay in the province.

But the carbon tax idea is not popular among producers, who fear it will hurt income and competitiveness, especially with their American counterparts who don’t have a carbon tax.

“There’s lots of work due for the recognition that agriculture is part of the solution, not the problem,” said Lewis, who is also president of the Agricultural Producers Association of Saskatchewan.

“Intuitively, farmers recognize you burn fuel, you spend more money, so intuitively for years, we’ve been on the carbon band wagon just from the practices we do.”

Jacob Froese, president of the Canadian Canola Growers Association, says the tax will go on fuel, fertilizer, and chemicals. Railroads that ship farm products will also face the tax and pass that onto farmers, he said.

The canola crushing industry could be in trouble because they compete globally with countries that don’t have a carbon tax, he suggested.

“We don’t want to be alarmists, but we want to be realists and look at what is coming down the road,” said Froese.

“They have to find a way to neutralize the tax on producers. We have picked all the low hanging fruit, so to speak. If you look at agriculture in Western Canada, it has revolutionized in the last 15, 20 years.”

Froese also says producers sequester a lot of carbon with the crops that they grow and haven’t been recognized for improvements that have been made.

Lewis says that’s why, despite disagreeing with Trudeau on the carbon tax, it was important to have the prime minister out to the farm and for producers to talk to him at the rink.

“We gotta start the conversation,” said Lewis.

“As somebody said once, if you’re not at the dinner table, you’re probably on the menu, and today we’re at the dinner table.”

Jennifer Graham, The Canadian Press

Suncor Energy reports voting results from Annual General Meeting

April 27, 2017 by The Canadian Press

FOR: SUNCOR ENERGY INC.TSX SYMBOL: SUNYSE SYMBOL: SUDate issue: April 27, 2017Time in: 6:11 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 27, 2017) – Suncor held its Annual
General Meeting in Calgary today. A total of approximately 1.2 billion…

Total Energy Services Inc. Announces Final Take-Up of Savanna Common Shares and Expiry of Offer

April 27, 2017 by The Canadian Press

FOR: TOTAL ENERGY SERVICES INC.TSX SYMBOL: TOTDate issue: April 27, 2017Time in: 5:53 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 27, 2017) – Total Energy Services Inc.
(“Total Energy”) (TSX:TOT) announced today that it has taken-up an addit…

Strad Energy Services Ltd. 2017 First Quarter – Conference Call

April 27, 2017 by The Canadian Press

FOR: STRAD ENERGY SERVICES LTD.
TSX SYMBOL: SDY

Date issue: April 27, 2017
Time in: 5:15 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 27, 2017) –

NOT FOR DISTRIBUTION TO U.S. NEWS WIRE SERVICES OR FOR DISSEMINATION IN THE U.S.

Strad Energy Services Ltd. (“Strad” or the “Company”) (TSX:SDY) will release
its 2017 first quarter financial results on Wednesday, May 10, 2017 after
market close. A conference call and webcast is scheduled on Thursday, May 11,
2017 at 8:00 a.m. MT to review these results. The call will be hosted by Andy
Pernal, President and Chief Executive Officer.

/T/

Date: Thursday, May 11, 2017
Time: 8:00 a.m. MT (10:00 a.m. ET)
Dial-in: 1-844-388-0561
Conf. ID: 93452009
Webcast: http://www.stradenergy.com/

/T/

Shortly after the conclusion of the call, a replay will be available by dialing
1-855-859-2056 and enter Conf. ID 93452009. The replay will expire on Thursday,
May 18, 2017, at 1:00 p.m. ET.

About Strad Energy Services Ltd.

Strad is a North American energy services company that provides rental
equipment and matting solutions to the oil and gas and energy infrastructure
sectors. Strad focuses on providing complete customer solutions in Canada and
the United States.

Strad is headquartered in Calgary, Alberta, Canada. Strad is listed on the
Toronto Stock Exchange under the trading symbol “SDY”.

The TSX has not reviewed and does not accept responsibility for the adequacy or
accuracy of this news release.

– END RELEASE – 27/04/2017

For further information:
Strad Energy Services Ltd.
Andy Pernal
President & Chief Executive Officer
(403) 775-9202
(403) 232-6901 (FAX)
apernal@stradenergy.com
OR
Strad Energy Services Ltd.
Michael Donovan
Chief Financial Officer
(403) 775-9221
(403) 232-6901 (FAX)
mdonovan@stradenergy.com

COMPANY:
FOR: STRAD ENERGY SERVICES LTD.
TSX SYMBOL: SDY

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170427CC0087

Press Release from Marketwired 1-866-736-3779

Suncor CEO says more oilsands deals may appear in ‘exodus’ of foreign firms

April 27, 2017April 27, 2017 by The Canadian Press

CALGARY — Suncor Energy (TSX:SU) has a potential opportunity to make further purchases in Alberta’s oilsands if foreign multinationals continue to exit the sector, the oil and gas company’s chief executive said Thursday.

Suncor feels no pressure to buy but is watching closely for opportunities and has the financial strength to act, Suncor CEO Steve Williams said Thursday on a quarterly conference call with analysts.

Williams said he doesn’t think the “exodus” from the Alberta oilsands by big international companies “is quite finished yet” and there are “known sellers out there if you look.”

“And so, there may be some incredible opportunities because I don’t think there are many companies out there now that have a balance sheet capable of purchase,” Williams said.

Suncor said in its quarterly report that completion of construction at the Fort Hills oilsands mine, estimated to cost $16.5 billion to $17 billion, and the $14-billion East Coast Hebron offshore project will free up its capital.

Both projects are expecting first production by year-end.

Suncor increased its ownership of Syncrude Canada last year to over 53 per cent in part by buying American firm Murphy Oil’s five per cent interest. It also bought Canadian Oil Sands’ 37 per cent stake and already had a 12 per cent stake.

Other foreign companies selling oilsands assets in the past year include Americans Marathon Oil and ConocoPhillips, Norway’s Statoil and British-Dutch oil giant Royal Dutch Shell.

Williams made his comments before the company’s annual shareholders meeting in Calgary and after the company released its first-quarter financial results late Wednesday.

Its first-quarter net earnings rose to $1.35 billion, compared with $257 million a year earlier.

The company said it may purchase up to $2 billion worth of its shares this year, but such buybacks aren’t mandatory.

Williams pointed out that Suncor’s proposed 80,000-barrel-per-day Meadow Creek East steam-driven oilsands project south of Fort McMurray in northern Alberta received regulatory approval in March.

He said the company has approvals on similar thermal projects that could produce about 400,000 bpd but won’t proceed with any until after 2020.

Suncor said it had total upstream production of 725,100 barrels of oil equivalent per day in the three months ended March 31, compared with 691,400 boe/d in the year-earlier quarter, driven mainly by its increased ownership interest in Syncrude Canada acquired during 2016.

Oilsands production came to 448,500 barrels per day in the first quarter of 2017.

Suncor cut its expectation for its share of Syncrude production this year by 15,000 bpd to between 135,000 and 150,000 bpd because of a fire at Syncrude’s Mildred Lake oilsands upgrader on March 14.

But Williams said strong performance at its East Coast and North Sea offshore projects allowed Suncor to add 15,000 barrels of oil equivalent per day to its expectations for non-oilsands production to leave its overall guidance unchanged.

Follow @HealingSlowly on Twitter.

The Canadian Press

Rumours rife as gas restrictions in N. Korean capital drag on

April 27, 2017 by The Canadian Press

PYONGYANG, Korea, Democratic People’s Republic Of — An acute shortage of gasoline in the North Korean capital of Pyongyang that has sparked price hikes and hoarding is raising fears of potentially crippling pain at the pumps if things don’t get better soon — and driving rumours that China is to blame.

The shortage, which is extremely unusual if not unprecedented, began last week when signs went up at gas stations around the city informing customers that restrictions on sales would be put in place until further notice. With no indication as of Wednesday night of when the restrictions might be lifted — or why they have been imposed — drivers continue to scramble to fill up their tanks and whatever other containers they can find.

Prices, meanwhile, have shot up. They had been fairly stable, typically at about 70-80 cents a kilogram, but on Wednesday at least one station was charging $1.40. Gasoline is sold by the kilogram in North Korean filling stations. One kilogram is roughly equivalent to one litre, so a gallon at the station costs about $5.30.

China supplies most of energy-poor North Korea’s fuel, and in lieu of official explanations, rumours are rife that Beijing is behind the shortage. The concerns are adding to a tense and uncertain mood on the Korean Peninsula since U.S. President Donald Trump assumed office with repeated calls for Beijing — Pyongyang’s economic lifeline — to get tough on North Korea, which has responded with counterclaims Washington is pushing for a nuclear war.

Though trade between North Korea and China appears to be solid, and possibly even growing, there are indications Beijing has been quietly tightening enforcement of some international sanctions aimed at getting Pyongyang to abandon its development of nuclear weapons and long-range missiles.

Limiting the oil supply has been openly discussed in Beijing as one option. Whether that is actually happening is unclear.

David von Hippel, a senior associate with the Nautilus Institute who specializes in energy and environmental issues, said supplies of crude oil and oil products would drop markedly without Chinese imports. But he stressed other factors could just as well be involved.

“The shortages and price rises being seen may be due to a combination of factors, including both actual shortages of products, more products being routed to other users — specific ministries, key factories, or the military, for example — and, or, more product being placed into government storage facilities,” he said in an email. “I do not have a sense, at present, of which of these options, and in what combination, is the driver for the price rises and sales restrictions.”

But two days after the restrictions were announced, North Korea’s state-run Korean Central News Agency carried an unusually acerbic, and even threatening, editorial denouncing “a country around the DPRK,” an obvious if not explicit reference to China. DPRK is short for North Korea’s official name — the Democratic People’s Republic of Korea.

“The DPRK’s nuclear deterrence for self-defence … is by no means a bargaining chip for getting something,” the commentary said, adding that if “the country” keeps applying economic sanctions “while dancing to the tune of someone … it may be applauded by the enemies of the DPRK but it should get itself ready to face the catastrophic consequences in the relations with the DPRK.”

It is unclear whether the gas shortage has affected North Korea’s military, state ministries and major projects, all of which get priority access to the state-controlled supply. But the North this month has staged a huge military parade, unveiled a sprawling high-rise residential district and on Tuesday conducted its biggest-ever live-fire air, land and sea military drill. It is also believed to be prepared to conduct what would be its sixth underground nuclear test.

Several chains of gas stations are operated under different state-run enterprises — some, for example, are operated by Air Koryo, the national flagship airline — and prices can vary.

North Korea gasoline customers usually purchase coupons at a cashier’s booth to fill up. Leftover coupons can be used on later visits until their expiration date. A common amount for the coupons is 15 kilograms (19.65 litres or 5.2 U.S. gallons).

The number of North Korean gas stations has grown steadily in recent years, mainly in Pyongyang, provincial capitals and along major highways. Pyongyang traffic has gotten significantly heavier since Kim Jong Un assumed power in late 2011. The greater number of cars, including swelling fleets of taxis, has been seen as an indication of greater economic activity.

Many of the vehicles are used for business purposes, such as transporting people or goods.

“When I last visited in 2005, they were filling up our bus with gas rations from buckets,” said Curtis Melvin, a researcher at the US-Korea Institute at Johns Hopkins University and a contributor to the 38 North website. “Things have definitely changed.”

Melvin added that the growth of an actual domestic market for gasoline has made it possible to see when there is a problem, since prices are posted at the gas stations, making trends publicly trackable. There is also less rationing than in the past.

If the apparent shortages are being caused by China, he said, the most likely explanation would be that less fuel is flowing across the border via pipeline.

Such a slowdown or stoppage would have an immediate impact on prices and would take time to compensate for by ships, trucks or trains. The primary place for North Korea pipeline storage tanks in China is in the border city of Dandong. But it was also not clear if North Korean tankers were picking up as much fuel as usual.

Eric Talmadge, The Associated Press

Poland signs first deal to buy natural gas from US supplier

April 27, 2017April 27, 2017 by The Canadian Press

WARSAW, Poland — Poland has signed its first deal to purchase liquefied natural gas from a U.S. supplier, a step that will help the country’s efforts to cut its dependence on deliveries from Russia, officials said Thursday.

The head of Polish gas giant PGNiG, Piotr Wozniak, called it a “historic moment” for the company which is “gaining a new partner in LNG trade” in North America and becoming a “gateway” that opens for U.S. gas in northern Europe.

His deputy in charge of trade, Maciej Wozniak, said the one-time delivery will arrive at the Baltic Sea port of Swinoujscie in early June from the Sabine Pass terminal located on the border between Texas and Louisiana. It will be the first U.S. LNG delivery to northern Europe.

Wozniak would not reveal the size of the delivery or the price of the deal with Houston-based Cheniere Energy, Inc. He only said the price was “good and attractive.”

Prime Minister Beata Szydlo said the deal helps Poland cut its dependence on deliveries from Russia. The country has been seeking to reduce its reliance on Moscow, which has used fuel as a tool to pressure some countries in the region in the past.

Among the steps was the opening last year of the Swinoujscie LNG port which is to supply Poland and others in the region. Poland also started importing gas from the Middle East, especially Qatar, and from Norway.

The U.S. is rich in shale gas and has been exporting fuel to southern European nations such as Spain and Turkey, but not yet to nations in the continent’s north.

___

This story has been corrected to show the name of the U.S. company is Cherniere, not Chernier.

Monika Scislowska, The Associated Press

Reports say oil and gas methane emissions higher than previously thought

April 27, 2017 by The Canadian Press

CALGARY — Two new reports from environmental groups say methane emissions in Canada’s oil and gas sector are higher than previously thought, as debate continues on how urgently they need to be reduced.

The David Suzuki Foundation partnered with St. Francis Xavier University on a study that found methane emissions from oil and gas sites in British Columbia to be 2.5 times higher than previously reported.

“Our finding is quite staggering,” said Ian Bruce, director of the Suzuki Foundation’s science and policy department.

“B.C.’s methane pollution problem, and certainly Canada’s, is much bigger than previously estimated by government and industry.”

The peer-reviewed findings, drawn from measures at over 1,600 well pads in the Montney shale gas formation in northeastern B.C., estimate that operations in the region leak and intentionally release more than 111,800 tonnes of methane annually.

“This is a concern because methane is a very potent greenhouse gas, 84 times more potent than carbon dioxide over a 20-year period,” said Bruce.

He said the effects of methane means its important for the federal government to return to its original timeline for reducing those emissions, rather than the at least three-year delay it recently made after pressure from industry.

Meanwhile, an Environmental Defence report highlighted data produced by GreenPath Energy Ltd. for the Alberta government that shows methane emissions in that province are 60 per cent higher than previously thought.

GreenPath surveyed 676 oil and gas wells on 395 sites across much of Alberta’s gas producing regions and found the number of pumps and controllers on sites that could leak methane was much higher than expected.

Using the updated figure, GreenPath concluded that the five gas-producing areas it studied would have 489,951 annual tonnes of methane emissions from those devices, compared with a 2014 report that showed 306,213 tonnes of methane emissions a year from unreported venting in 2010 for all of Alberta.

Environmental Defence national program manager Dale Marshall said it was concerning that there seems to be an under-reporting of the number of devices on these sites.

“If there are many more devices than being reported at facilities, then either they’re under-reporting on purpose, or they don’t know. Either way it’s problematic,” he said.

Marshall said that more should be done to reduce methane emissions because it’s one of the lowest cost solutions to reducing greenhouse gas emissions overall.

Joshua Anhalt, president at GreenPath North America, said that while the number of devices found in the study was higher than anticipated, there’s still the potential for that number to go even higher since there’s still a lot to learn on methane emissions.

“We’ve only looked at the tip of the iceberg as an industry,” said Anhalt, adding that the good news is there are technologies readily available to quickly reduce or eliminate leaking methane.

Chelsie Klassen, spokeswoman for the Canadian Association of Petroleum Producers, however, challenged the findings of the studies and questioned their methodology.

“Industry does not support the findings or recommendations of these studies due to their limited scope and misrepresentation of reporting mechanisms currently in place,” Klassen said in an email.

She said there are requirements in place to detect and repair leaks, and industry has been working with regulators and governments on ways to further reduce emissions.

CAPP has, however, also pushed to delay new federal methane regulations, saying in submissions released under access to information that the proposed timeline is aggressive and that it is not a good time to impose extra costs on industry.

The association said it is committed to the target of a 40 to 45 per cent methane emission reduction by 2025 from 2012 levels, but looking for more flexibility on how to get there.

— With files from Mia Rabson in Ottawa

Ian Bickis, The Canadian Press

UAE’s first solar-powered gas station opens in Dubai

April 27, 2017April 27, 2017 by The Canadian Press

DUBAI, United Arab Emirates — A government oil company in the United Arab Emirates says it has opened the country’s first solar-powered gas station in Dubai.

The Dubai-owned Emirates National Oil Company said on Wednesday the service station on the city’s main Sheikh Zayed Road thoroughfare is covered with solar panels that can generate up to 120 kilowatt hours.

ENOC says that is about 30 per cent more energy than the station needs, so the excess power is directed back into the city’s electric grid.

Although it is OPEC’s fourth biggest oil producer, the UAE has made a push to turn itself into a hub for renewable energy. It is building multiple solar farms and hosts the global headquarters of the International Renewable Energy Agency.

The Associated Press

Relentless Announces Year-End 2016 Results and Filing of Reserves Disclosure

April 27, 2017 by The Canadian Press

FOR: RELENTLESS RESOURCES LTD.
TSX VENTURE SYMBOL: RRL

Date issue: April 27, 2017
Time in: 10:10 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 27, 2017) – Relentless Resources Ltd.
(“Relentless” or the “Company”) (TSX VENTURE:RRL) announces the filing of its
audited financial statements and related management’s discussion and analysis
(“MD&A”) for the year ended December 31, 2016. The Company also announces the
filing of its reserves data and other oil and natural gas information (“51-101
Information”), as required under National Instrument 51-101. The financial
statements, MD&A and 51-101 Information are available for review at
www.sedar.com. Additional information about Relentless is available on SEDAR at
www.sedar.com or on the Company’s website at www.relentless-resources.com.

Recent Highlights

/T/

– In Q4 of 2016, the Company expended approximately $1.5 million to drill

and complete two new wells in Heathdale, Alberta:

– 102/5-7-27-9W4 horizontal oil well:

– drilled in eight days to a total measured depth of 2,375 metres;
– perforated over 23 intervals and fracture stimulated using a coil
tubing straddle packer assembly; placed on stream in mid-January with
a spud to on-stream timeline of 35 days inclusive of the holidays;
– total on-stream cost of $1.17 million as a one-off single well
operation;
– continual production with minimal downtime and a high fluid level;
– averaged 100 boe/d (80% oil) for the first 60 days; and
– continues to produce at 80 boe/d (75% oil).

– 100/6-12-27-10W4 vertical well:

– drilled approximately 1.2 kilometres west of the known Heathdale
glauconitic oil pool;
– encountered approximately five meters of glauconitic oil reservoir at
virgin pressure;
– total on-stream cost of $425,000 equipped as a single well battery;
and
– fifth section of land in which Relentless has confirmed the presence
of this glauconite oil deposit.

– The Company’s net debt was reduced from approximately $4.05 million, as at

December 31, 2016, to approximately $3.05 million as a result of the
completion of two private placements in January 2017.

– The Heathdale glauconite oil pool have been successfully delineated with

five vertical wells and developed with four horizontal multistage
fractured wells.

– Current corporate production is estimated at 275 boe/d (60% oil and

liquids). Fifty boe/d is currently shut in as a result of a third party
compressor outage and is anticipated to return to production in Q2 2017.

/T/

Cash Flow, Comprehensive Loss and Netbacks

/T/

—————————————————————————-
Three months
ended December % 2016 2015 %
31, 2016 2015 Change ($ / boe) ($ / boe) Change
—————————————————————————-
Oil and natural
gas sales 606,421 613,309 (1) 34.26 29.68 15
Royalties (53,717) (35,565) 51 (3.03) (1.72) 76
—————————————————————————-
Revenue after
royalties 552,704 577,744 (4) 31.23 27.96 12
Production,
operating and
transportation
expenses (309,960) (303,177) 2 (17.51) (14.67) 19
—————————————————————————-
Operating cash
flow (1) 242,744 274,567 (12) 13.72 13.29 3
General &
administrative
expenses (102,106) (109,994) (7) (5.77) (5.32) 8
Interest and
other financing
charges (34,489) (36,305) (5) (1.95) (1.76) 11
Bad debt expense – (181,018) (100) 0.00 (8.76) (100)
Flow through
share
indemnification
expense – (15,732) (100) 0.00 (0.76) (100)
—————————————————————————-
Cash flow from
operations (1) 106,149 (68,482) (255) 6.00 (3.31) (281)
Other income 393,750 26,192 1,403 22.25 1.27 1652
Gain on
disposition 99,504 5.62 0.00 100
Share based
compensation – – – 0.00 0.00 –
Accretion (10,799) 21,758 (150) (0.61) 1.05 (158)
Impairment 59,050 (234,506) (125) 3.34 (11.35) (129)
Depletion and
depreciation (135,807) (138,500) (2) (7.67) (6.70) 14
—————————————————————————-
Comprehensive
income (loss) 511,847 (393,538) (230) 28.93 (19.04) (252)
—————————————————————————-
$ Per Share –
Basic 0.01 (0.01)
$ Per Share –
Diluted 0.01 (0.01)
—————————————————————————-
—————————————————————————-
Year ended % 2016 2015 %
December 31, 2016 2015 Change ($ / boe) ($ / boe) Change
—————————————————————————-
Oil and natural
gas sales 2,030,043 3,331,944 (39) 29.54 32.91 (10)
Royalties (171,064) (413,605) (59) (2.49) (4.08) (39)
—————————————————————————-
Revenue after
royalties 1,858,979 2,918,339 (36) 27.05 28.83 (6)
Production,
operating and
transportation
expenses (1,011,344) (1,506,848) (33) (14.71) (14.88) (1)
—————————————————————————-
Operating cash
flow (1) 847,635 1,411,491 (40) 12.33 13.95 (12)
General &
administrative
expenses (475,096) (551,445) (14) (6.91) (5.45) 27
Interest and
other financing
charges (139,562) (72,628) 92 (2.03) (0.72) 183
Bad debt expense – (181,018) (100) 0.00 (1.79) (100)
Flow through
share
indemnification
expense – (15,732) (100) 0.00 (0.16) (100)
—————————————————————————-
Cash flow from
operations (1) 232,977 590,668 (61) 3.39 5.83 (42)
Other income 393,750 305,223 29 5.73 3.01 90
Gain on
disposition 99,504 – 1.45 0.00 100
Share based
compensation – (132,027) (100) 0.00 (1.30) (100)
Accretion (54,681) (64,901) (16) (0.80) (0.64) 24
Impairment (96,725) (1,903,931) (95) (1.41) (18.80) (93)
Depletion and
depreciation (819,719) (1,390,068) (41) (11.93) (13.73) (13)
—————————————————————————-
Comprehensive
loss (244,894) (2,595,036) (91) (3.56) (25.63) (86)
—————————————————————————-
$ Per Share –
Basic (0.00) (0.04)
$ Per Share –
Diluted (0.00) (0.04)
—————————————————————————-

/T/

(1) Non-IFRS measure

Daily Production and Commodity Prices

/T/

—————————————————————————-

Three months ended December 31
—————————————————————————-
2016 2015 % Change
—————————————————————————-
Daily production
Oil and NGLs (bbl/d) 96 125 (23)
Natural gas (mcf/d) 581 600 (3)
—————————————————————————-
Oil equivalent (boe/d @ 6:1) 192 225 (15)
—————————————————————————-

Realized commodity prices ($CDN)
Oil and NGLs (bbl) $ 50.17 $ 40.62 24
Natural gas (mcf) $ 3.10 $ 2.67 16
—————————————————————————-
Oil equivalent (boe @ 6:1) $ 34.26 $ 29.68 15
—————————————————————————-

—————————————————————————-

Years ended December 31
—————————————————————————-
2016 2015 % Change
—————————————————————————-
Daily production
Oil and NGLs (bbl/d) 103 150 (31)
Natural gas (mcf/d) 511 766 (33)
—————————————————————————-
Oil equivalent (boe/d @ 6:1) 188 278 (32)
—————————————————————————-

Realized commodity prices ($CDN)
Oil and NGLs (bbl) $ 42.18 $ 47.95 (12)
Natural gas (mcf) $ 2.37 $ 2.55 (7)
—————————————————————————-
Oil equivalent (boe @ 6:1) $ 29.54 $ 32.91 (10)
—————————————————————————-

/T/

Reserves Data

The reserves data set forth below (the “Reserves Data”) is based upon a report
prepared by Trimble Engineering Associates Ltd. independent petroleum
consultants of Calgary, Alberta, evaluating the crude oil, natural gas and
natural gas liquids (“NGL”) reserves of Relentless, as at December 31, 2016,
with a preparation date of April 11, 2017 (the “Trimble Report”). The Reserves
Data summarizes the crude oil, NGL and natural gas reserves of the Company and
the net present values of future net revenue for these reserves using forecast
prices and costs. The Trimble Report is available for review on the Company’s
profile on www.sedar.com.

OIL AND GAS RESERVES SUMMARY

/T/

Light & Medium Crude
Reserve Category Oil Solution Gas
Gross Net Gross Net
Mstb Mstb MMcf MMcf
—————————————————————————-
Proved
Developed Producing 249.4 222.8 1,028.2 906.0
Developed Non-producing 60.0 49.9 113.5 89.3
Undeveloped 270.0 228.8 446.3 370.6
Total Proved 579.4 501.5 1,588.0 1,366.0
Total Probable 502.9 432.3 1,034.5 883.4
Total Proved Plus Probable 1,082.3 933.7 2,622.5 2,249.4

Conventional
Reserve Category Natural Gas NGL BOE
Gross Net Gross Net Gross Net
MMcf MMcf Mstb Mstb Mboe Mboe
—————————————————————————-
Proved
Developed Producing 506.2 441.0 26.8 18.0 531.9 465.4
Developed Non-producing – – 1.0 0.7 79.9 65.5
Undeveloped – – 4.0 3.3 348.4 293.9
Total Proved 506.2 441.0 31.8 22.1 960.2 824.7
Total Probable 170.2 150.9 14.3 11.3 718.0 615.9
Total Proved Plus Probable 676.3 591.9 46.1 33.4 1,678.2 1,440.6

/T/

NET PRESENT VALUES OF FUTURE NET REVENUE BEFORE INCOME TAXES DISCOUNTED AT
(%/YEAR)

(FORECAST COSTS AND PRICES)

/T/

Reserve Category 0% (BTax) 5% (BTax) 10% (BTax) 15% (BTax) 20% (BTax) 10%
M$ M$ M$ M$ M$ $/boe
—————————————————————————-
Proved
Developed
Producing 11,391.6 8,788.1 7,118.4 5,993.5 5,197.4 15.30
Developed Non-
producing 2,862.5 2,267.6 1,883.9 1,622.4 1,435.6 28.76
Undeveloped 9,546.3 6,868.6 5,163.5 4,015.1 3,204.1 17.57
Total Proved 23,800.4 17,924.3 14,165.8 11,631.1 9,837.0 17.18
Total Probable 26,907.6 15,692.0 10,407.8 7,557.9 5,832.5 16.90
Total Proved
Plus Probable 50,708.0 33,616.3 24,573.5 19,188.9 15,669.5 17.06

/T/

About Relentless Resources Ltd.

Relentless is a Calgary based emerging oil and natural gas company, engaged in
the exploration, development, acquisition and production of natural gas and
light gravity crude oil reserves in Alberta, Canada. Relentless’s common shares
trade on the TSX Venture Exchange under the symbol RRL.

Relentless’s primary corporate objective is to achieve non-dilutive growth and
enhance shareholder value through internal prospect development, strategic
production acquisitions and prudent financial management.

Forward-Looking Statements: All statements, other than statements of historical
fact, set forth in this news release, including without limitation, assumptions
and statements regarding the volumes and estimated value of the Company’s
proved and probable reserve s, future production rates, exploration and
development results, financial results, and future plans, operations and
objectives of the Company are forward-looking statements that involve
substantial known and unknown risks and uncertainties. Some of these risks and
uncertainties are beyond management’s control, including but not limited to,
the impact of general economic conditions, industry conditions, fluctuation of
commodity prices, fluctuation of foreign exchange rates, environmental risks,
industry competition, availability of qualified personnel and management,
availability of materials, equipment and third party services, stock market
volatility, timely and cost effective access to sufficient capital from
internal and external sources. The reader is cautioned that assumptions used in
the preparation of such information, although considered reasonable by the
Company at the time of preparation, may prove to be incorrect. There can be no
assurance that such statements will prove to be accurate and actual results and
future events could differ materially from those anticipated in such statements.

These assumptions and statements necessarily involve known and unknown risks
and uncertainties inherent in the oil and gas industry such as geological,
technical, drilling and processing problems and other risks and uncertainties,
as well as the business risks discussed in the MD&A under the heading “Business
Risks”. The Company does not undertake any obligation, except as required by
applicable securities legislation, to update publicly or to revise any of the
included forward-looking statements, whether as a result of new information,
future events or otherwise.

Barrels of oil equivalent (boe) is calculated using the conversion factor of 6
mcf (thousand cubic feet) of natural gas being equivalent to one barrel of oil.
Boes may be misleading, particularly if used in isolation. A boe conversion
ratio of 6 mcf:1 bbl (barrel of oil) is based on an energy equivalency
conversion method primarily applicable at the burner tip and does not represent
a value equivalency at the wellhead. Given that the value ratio based on the
current price of crude oil as compared to natural gas is significantly
different from the energy equivalency of 6:1, utilizing a conversion on a 6:1
basis may be misleading as an indication of value. Boe/d means boe per day.

Any references in this press release to initial, early and/or test
production/performance rates are useful in confirming the presence of
hydrocarbons, however, such rates are not determinative of the rates at which
such wells will continue production and decline thereafter. While encouraging,
readers are cautioned not to place reliance on such rates in calculating
aggregate production. The initial production rate may be estimated based on
other third party estimates or limited data available at this time. Initial
production or test rates are not necessarily indicative of long-term
performance of the relevant well or fields or of ultimate recovery of
hydrocarbons.

This press release provides certain financial measures that do not have a
standardized meaning prescribed by IFRS. These non -IFRS financial measures may
not be comparable to similar measures presented by other issuers. Cash flow
from operations and net surplus (debt) are not recognized measures under IFRS.
Management believes that in addition to net income (loss), cash flow from
operations and net surplus (debt) are useful supplemental measures that
demonstrate the Company’s ability to generate the cash necessary to repay debt
or fund future capital investment. Investors are cautioned, however, that these
measures should not be construed as an alternative to net income (loss)
determined in accordance with IFRS as an indication of the Company’s
performance. The Company’s method of calculating these measures may differ from
other companies and accordingly, they may not be comparable to measures used by
other companies. Cash flow from operations is calculated by adjusting net
income (loss) for other income, unrealized gains or losses on financial
derivative instruments, transaction costs, accretion, share based compensation,
impairment and depletion and depreciation. Net surplus (debt) is the total of
cash plus accounts receivable, prepaids and deposits, less accounts payable
plus bank debt.

Neither TSX Venture Exchange nor its Regulation Services Provider (as that term
is defined in the policies of the TSX Venture Exchange) accepts responsibility
for the adequacy or accuracy of this release.

– END RELEASE – 27/04/2017

For further information:
Relentless Resources Ltd.
Dan Wilson
CEO
(403) 532-4466 ext. 227 or Mobile: (403) 874-9862
(587) 955-9668 (FAX)
OR
Relentless Resources Ltd.
Ron Peshke
President
(403) 532-4466 ext. 223 or Mobile: (403) 852-3403
(587) 955-9668 (FAX)
info@relentless-resources.com
www.relentless-resources.com

COMPANY:
FOR: RELENTLESS RESOURCES LTD.
TSX VENTURE SYMBOL: RRL

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170427CC0046

Press Release from Marketwired 1-866-736-3779

Marksmen Announces Consolidated Financial Results for the Year Ended December 31, 2016 and Operational Update

April 27, 2017 by The Canadian Press

FOR: MARKSMEN ENERGY INC.
TSX VENTURE SYMBOL: MAH
OTCQB SYMBOL: MKSEF

Date issue: April 27, 2017
Time in: 9:01 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 27, 2017) – Marksmen Energy Inc.
(“Marksmen” or the “Company”) (TSX VENTURE:MAH)(OTCQB:MKSEF) and its wholly
owned subsidiary Marksmen Energy USA, Inc. announces financial results for the
year ended December 31, 2016. The following documents have been filed on SEDAR:

/T/

— Audited Financial Statements
— Management’s Discussion and Analysis (“MD&A”)
— Form NI 51-101F1 Statement of Reserve Data and Other Oil and Gas

Information.
— Form NI 51-101F2 Report on Reserves Data by Independent Qualified
Reserve Evaluator
— Form NI 51-101F3 Report of Management and Directors on Oil and Gas
Disclosure
— Annual Information Form (“AIF”)

/T/

These filings may be viewed on the SEDAR website at www.sedar.com.

Highlights for fiscal years ended December 31, 2016 and 2015

Selected financial and operational information for the financial year ended
December 31, 2016 is set out below and should be read in conjunction with
Marksmen’s audited financial statements, the related MD&A and the report on
reserves data.

/T/

YE Dec 31 YE Dec 31
Highlights 2016 2015
—————————————————————————-

Oil production – bbls 12,455 5,996

Proved Reserves – Mbbls 74.9 23.8
Probable Reserves – Mbbls 90.0 50.2
—————————-
Total Proved and Probable – Mbbls 164.9 74.0

Revenue $ 743,976 $ 353,593
Revenue – bbl $ 59.73 $ 58.97

Cash flow used in operations $ (390,747)$ (773,863)
Per share – basic and diluted $ -0.01 $ -0.01

Impairment (Recovery) $ (655,110)$ 640,351

Net Loss $ (64,183)$ (773,863)
Per share – basic and diluted $ -0.00 $ -0.01

Assets $ 4,723,592 $ 3,984,231
Liabilities $ 1,829,139 $ 2,000,119

Weighted average shares outstanding 72,662,453 60,485,588

/T/

In 2016 Marksmen experienced significant improvements in its financial and
production performance over 2015. Oil production and revenue more than doubled,
proved reserves more than tripled and probable reserves almost doubled.
Negative cash flow from operations was cut in half, and impairment of assets
was fully reversed due to improved reserves.

Operational Update and Outlook

In June of 2016 the Company drilled the Davis-Holbrook #1 well and it was put
on production in mid-July. It has contributed significantly to the revenue of
the Company in the second half of 2016. The total production from this well to
December 31, 2016 is 13,223 barrels (9,917 barrels net to Marksmen). As of the
end of March 2017 the well has produced an additional 6,113 gross barrels
(4,584 net barrels) for a total to date for the well of 19,335 barrels (14,507
barrels net).

The well at Delong Davis #1, drilled in 2015 was deepened in February 2017 at a
capital cost of approximately $30,000 USD. The well has improved its production
from 1 to 2 gross barrels of oil per day to over 30 gross barrels per day (net
13.5 barrels of oil per day to Marksmen).

Marksmen is currently evaluating offset drilling opportunities on its current
land position as well as other land, 3D seismic and drilling opportunities in
Ohio.

Marksmen also announces the granting of stock options to purchase 575,000
common shares of the Company to directors, executive officers and consultants
subject to regulatory and TSX Venture Exchange approval. The options were
issued with an exercise price of $0.10 per share, vest as to one-third (1/3)
immediately and one-third (1/3) on each of the first and second anniversaries
of the grant date and have a five year term from the date of issuance.

This news release may contain certain forward-looking information and
statements including drilling and other opportunities available to Marksmen.
All statements included herein, other than statements of historical fact, are
forward-looking information and such information involves various risks and
uncertainties. There can be no assurance that such information will prove to be
accurate, and actual results and future events could differ materially from
those anticipated in such information. A description of assumptions used to
develop such forward-looking information and a description of risk factors that
may cause actual results to differ materially from forward-looking information
can be found in Marksmen’s disclosure documents on the SEDAR website at
www.sedar.com. Marksmen does not undertake to update any forward-looking
information except in accordance with applicable securities laws.

– END RELEASE – 27/04/2017

For further information:
Marksmen Energy Inc.
Archie Nesbitt
CEO and President
(403) 265-7270
info@marksmen.ca

COMPANY:
FOR: MARKSMEN ENERGY INC.
TSX VENTURE SYMBOL: MAH
OTCQB SYMBOL: MKSEF

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170427CC0038

Press Release from Marketwired 1-866-736-3779

DIVERGENT Energy Services Announces Operations Update

April 27, 2017 by The Canadian Press

FOR: DIVERGENT ENERGY SERVICES CORP.TSX VENTURE SYMBOL: DVGDate issue: April 27, 2017Time in: 9:00 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 27, 2017) –
NOT FOR DISSEMINATION IN THE UNITED STATES OF AMERICA
DIVERGENT Energy Services Corp. …

AltaGas Ltd. Announces Election of Directors

April 27, 2017 by The Canadian Press

FOR: ALTAGAS LTD.TSX SYMBOL: ALADate issue: April 27, 2017Time in: 8:45 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 27, 2017) – AltaGas Ltd. (“AltaGas”)
(TSX:ALA) is pleased to announce the final director election results from its
2017 Annua…

Pan Orient Energy Corp.: East Jabung PSC AYU-1X Exploration Well Update

April 27, 2017 by The Canadian Press

FOR: PAN ORIENT ENERGY CORP.
TSX VENTURE SYMBOL: POE

Date issue: April 27, 2017
Time in: 8:30 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 27, 2017) –

Pan Orient Energy Corp. (“Pan Orient” or the “Company”) (TSX VENTURE:POE) is
providing an operations update.

INDONESIA

East Jabung PSC (POE 49% & Non Operator)

The operator of the East Jabung Production Sharing Contract indicated to the
Company on April 25 that due to delays related to unusually heavy monsoon
rainfall, the estimated commencement of drilling of the AYU-1X exploration well
has been delayed from late April to late Q2 2017. This delay has been due to
the implementation of extraordinary measures that were required to mitigate the
extremely wet conditions caused by continuous rainfall with some days recording
as much as 7.6 centimeters of precipitation.

The Company will continue to update shareholders on any timeline revisions,
should they occur, and also announce the commencement of drilling, when this
occurs.

Pan Orient is a Calgary, Alberta based oil and gas exploration and production
company with operations currently located onshore Thailand, Indonesia and in
Western Canada.

This press release contains forward-looking information. Forward-looking
information is generally identifiable by the terminology used, such as
“expect”, “believe”, “estimate”, “should”, “anticipate” and “potential” or
other similar wording. Forward-looking information in this press release
includes references, express or implied, to the timing of drilling in
Indonesia. By its very nature, the forward-looking information contained in
this press release requires Pan Orient and its management to make assumptions
that may not materialize or that may not be accurate. In addition, the
forward-looking information is subject to known and unknown risks and
uncertainties and other factors, some of which are beyond the control of Pan
Orient, which could cause actual results, expectations, achievements or
performance to differ materially. Although Pan Orient believes that the
expectations reflected in its forward-looking information are reasonable, it
can give no assurances that those expectations will prove to be correct. Pan
Orient undertakes no obligation to update publicly or revise any
forward-looking information, whether as a result of new information, future
events or otherwise, except as required by applicable securities laws.

– END RELEASE – 27/04/2017

For further information:
Pan Orient Energy Corp.
Jeff Chisholm
President and CEO (located in Bangkok, Thailand)
jeff@panorient.ca
OR
Bill Ostlund
Vice President Finance and CFO
(403) 294-1770

COMPANY:
FOR: PAN ORIENT ENERGY CORP.
TSX VENTURE SYMBOL: POE

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170427CC0032

Press Release from Marketwired 1-866-736-3779

Manitok Energy Inc. Announces the Acquisition of Natural Gas Production and Related Strategic Pipeline System and A Year Over Year First Quarter Production Increase of 39%

April 27, 2017 by The Canadian Press

FOR: MANITOK ENERGY INC.
TSX VENTURE SYMBOL: MEI

Date issue: April 27, 2017
Time in: 7:30 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 27, 2017) –

NOT FOR DISTRIBUTION TO U.S. NEWSWIRE SERVICES OR FOR DISSEMINATION IN THE
UNITED STATES OF AMERICA.

Manitok Energy Inc. (“Manitok” or the “Corporation”) (TSX VENTURE:MEI) is
pleased to announce that it has completed an acquisition from an Alberta based
oil and gas company to acquire a 100% working interest in approximately 1.1
Mmcf/d (175 boe/d) of natural gas production, based on field estimates, in the
Carseland, Alberta area (the “Acquisition”). In addition to the current
production, the Acquisition includes 13 sections of developed P&NG rights to
the base of the Belly River formation complete with full 3D seismic coverage,
and approximately 170 kilometers of related gathering systems extending over 3
townships. The Corporation paid a cash consideration of $75,000 and assumed
discounted abandonment liabilities of approximately $400,000 (10% discount
rate) for the Acquisition.

The Acquisition is of value to Manitok in the following ways:

/T/

— the acquired gathering system contains a segment of pipeline that will

facilitate a lower cost tie-in for four Manitok wells; two Basal Quartz
(“BQ”) wells located on the surface pad at 3-16-23-25W4M and two Lithic
Glauc (“LG”) wells located on the surface pad at 07-03-23-25W4M. The
location of the existing pipeline is expected to reduce the installation
costs associated with the tie-ins by about $1.0 million;

— the acquired gathering system extends Manitok’s infrastructure reach in

its core Carseland area over 3.5 townships making it less costly to tie
in wells drilled in the future as well as increasing the potential for
securing future third party volumes for the Carseland gas plant; and

— Manitok has estimated recompletion potential in approximately 40 of the

acquired wellbores and the lands associated with the Acquisition are
contiguous to the Corporation’s Carseland block.

/T/

Production and Operations Update

Based on field estimates, Manitok’s net production averaged 6,120 boe/d (38%
oil and liquids) during the first quarter of 2017 which is a 39% increase over
first quarter 2016 average production of 4,407 boe/d (46% oil). Approximately
75 boe/d was lost to unanticipated production down time during the quarter.

The year over year production increase was achieved even though there has not
been any additional production added from drilling since December 2016 due to
the inability to complete (i.e.: fracture stimulate) the last two horizontal
wells that were drilled late in 2016. Manitok was unable to complete the final
two wells of the 2016 drilling program due to the lack of availability of frac
crews over the winter drilling season. Manitok expects to complete and
production test these two wells late in the second quarter of 2017 and, if
successful, tie them in at the same time as the three wells discussed in more
detail below.

With the acquisition of the additional pipeline infrastructure in the Carseland
area, Manitok anticipates it will tie-in the following three horizontal wells
late in the second quarter of 2017:

/T/

— 02-09-23-25W4M (now 102/07-09-23-25W4M by name change) (the “07-09

well”): a lower BQ well that was drilled in 2014 and production tested
for 206 consecutive hours until stable flowing conditions were observed.
During the test period, the 07-09 well averaged 22.8 bbl/d oil and 989.6
Mcf/d natural gas for an average total of 186.2 boe/d and during the
last 24 hours of the test period, the 07-09 well produced 15.1 bbl/d oil
and 992.6 Mcf/d natural gas for an average of 179.0 boe/d;

— 03-09-23-25W4M (the “03-09 well”): a middle BQ well that was drilled in

2014 and production tested for 147 consecutive hours until stable
flowing conditions were observed. During the test period, the 03-09 well
averaged 137.2 bbl/d oil and 623.0 Mcf/d natural gas for an average
total of 240.1 boe/d and during the last 24 hours of the test period,
the 03-09 well produced 153.5 bbl/d oil and 1,208.0 Mcf/d natural gas
for an average of 353.0 boe/d; and

— 10-04-23-25W4M (the “10-04 well”): a LG well that was drilled in 2016

and production tested for 253 consecutive hours until stable flowing
conditions were observed. During the test period, the 10-04 well
averaged 170.8 bbl/d oil and 402.6 Mcf/d natural gas for an average
total of 237.3 boe/d and during the last 24 hours of the test period,
the 10-04 well produced 215.5 bbl/d oil and 514.7 Mcf/d natural gas for
an average of 300.5 boe/d.

/T/

Manitok anticipates adding approximately 800 boe/d (45% oil) of initial
production from these three already completed wells and further anticipates
additional volumes at Carseland when the two yet to be completed wells referred
to above are successfully completed.

Projected Disclosure Timing – Year-End Financials, Year-End Reserves and
Quarterly Financials

Manitok expects to announce its year-end financial results and to disclose its
year-end reserves information on or about May 1, 2017. First Quarter 2017
financial results will be released no later than May 30, 2017.

About Manitok

Manitok is a public oil and gas exploration and development company focused on
Lithic Glauconitic light oil in southeast Alberta and Cardium light oil in west
central Alberta. The Corporation utilizes its expertise, combined with the
latest recovery techniques, to develop the remaining oil and liquids-rich
natural gas pools in its core areas of the Western Canadian Sedimentary Basin.

For further information view our website at www.manitokenergy.com.

Cautionary Statements:

Forward-looking Information

This press release contains forward-looking statements. The forward-looking
statements in this press release are based on certain key expectations and
assumptions made by Manitok, including expectations and assumptions concerning
Manitok’s operational and drilling plans, development and growth potential of
Manitok’s properties, commodity prices, the anticipated benefits of the
Acquisition and the anticipated availability of capital.

Although Manitok believes that the expectations and assumptions on which the
forward-looking statements are based are reasonable, undue reliance should not
be placed on the forward-looking statements because Manitok can give no
assurance that they will prove to be correct. Since forward-looking statements
address future events and conditions, by their very nature they involve
inherent risks and uncertainties. Actual results could differ materially from
those currently anticipated due to a number of factors and risks. These
include, but are not limited to, risks associated with adverse market
conditions, the inability of the Corporation to complete the Acquisition at all
or on the terms announced, the TSX Venture Exchange not approving the
Acquisition, Manitok’s lender not approving the Acquisition and the risks
associated with the oil and gas industry in general (e.g., operational risks in
development, exploration and production; delays or changes in plans with
respect to exploration or development projects or capital expenditures; the
uncertainty of reserves estimates; the uncertainty of estimates and projections
relating to production, costs and expenses; and health, safety and
environmental risks), uncertainty as to the availability of labour and
services, commodity price and exchange rate fluctuations, unexpected adverse
weather conditions, general business, economic, competitive, political and
social uncertainties, capital market conditions and market prices for
securities and changes to existing laws and regulations. Certain of these risks
are set out in more detail in the AIF, which is available on Manitok’s SEDAR
profile at www.sedar.com.

Forward-looking statements are based on estimates and opinions of management of
Manitok at the time the statements are presented. Manitok may, as considered
necessary in the circumstances, update or revise such forward-looking
statements, whether as a result of new information, future events or otherwise,
but Manitok undertakes no obligation to update or revise any forward-looking
statements, except as required by applicable securities laws.

Well Production Test Information

Manitok cautions readers that the well production results reported herein may
not be indicative of long term well performance. Readers are advised to refer
to all available publicly disclosed information about the Company’s areas of
operation and well type curves in order to assess the probable long term well
performance associated with the production test results disclosed herein.

Barrels of Oil Equivalent

The term barrels of oil equivalent (“boe”) may be misleading, particularly if
used in isolation. Per boe amounts have been calculated using a conversion
ratio of six thousand cubic feet (6 mcf) of natural gas to one barrel (1 bbl)
of crude oil. The boe conversion ratio of 6 mcf to 1 bbl is based on an energy
equivalency conversion method primarily applicable at the burner tip and does
not represent a value equivalency at the wellhead. Given that the value ratio
based on the current price of crude oil as compared to natural gas is
significantly different from the energy equivalency of 6:1, utilizing a
conversion on a 6:1 basis may be misleading as an indication of value.

– END RELEASE – 27/04/2017

For further information:
Manitok Energy Inc.
Massimo M. Geremia
President and Chief Executive Officer
403-984-1751
mass@manitok.com
www.manitokenergy.com

COMPANY:
FOR: MANITOK ENERGY INC.
TSX VENTURE SYMBOL: MEI

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170427CC0022

Press Release from Marketwired 1-866-736-3779

Crescent Point Announces Q1 2017 Results With Production Ahead of Guidance

April 27, 2017 by The Canadian Press

FOR: CRESCENT POINT ENERGY CORP.
TSX SYMBOL: CPG
NYSE SYMBOL: CPG

Date issue: April 27, 2017
Time in: 6:30 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 27, 2017) –

All financial figures are approximate and in Canadian dollars unless otherwise
noted. This press release contains forward-looking information and references
to non-GAAP financial measures. Significant related assumptions and risk
factors, and reconciliations are described under the Non-GAAP Financial
Measures and the Forward-Looking Statements and Reserves Data sections of this
news release, respectively.

Crescent Point Energy Corp. (“Crescent Point” or the “Company”)
(TSX:CPG)(NYSE:CPG) is pleased to announce its operating and financial results
for the quarter ended March 31, 2017.

KEY HIGHLIGHTS

/T/

— Exceeded first quarter 2017 average production guidance. Expect to

revisit 2017 budget after spring break-up.
— Increased horizontal inventory in the Uinta Basin by 80 additional
locations, an increase of approximately 70 percent.
— Advanced new technologies including the installation of its Injection
Control Device (“ICD”) waterflood system.
— Hosting a technical day for investors in May 2017 as part of overall
efforts to enhance investor communication.

/T/

“Our focus in 2017 continues to be executing our organic growth plan and
delivering exit production growth of 10 percent per share,” said Scott Saxberg,
president and CEO of Crescent Point. “Our strong first quarter results
demonstrate this focus and the success we are achieving within our resource
plays.”

OPERATIONAL HIGHLIGHTS

/T/

— Crescent Point achieved average production of 173,329 boe/d ahead of

first quarter guidance of 170,000 boe/d. This is an increase of eight
percent compared to third quarter 2016, when the Company accelerated its
capital program as a result of the success of its new play development.
— In the Uinta Basin, Crescent Point expanded its horizontal inventory by
internally identifying 80 net new Castle Peak horizontal locations
during first quarter. The Company now has a total of approximately 200
net horizontal locations in the Castle Peak zone based on spacing of
four wells per section. Crescent Point continues to expand the play by
testing increased lateral lengths, increasing stages and tonnage per
stage, down-spacing and targeting new zones.
— In the Williston Basin, the Company remains focused on low-risk, high-
return infill development and down-spacing programs. The Company’s
successful step-out drilling program continues to expand the North
Dakota Three Forks play across the Canadian border. Crescent Point has
approximately 10 years of drilling inventory across multiple zones
within the basin.
— Crescent Point continues to advance its ICD waterflood system following
up on the success of its initial pilot in late 2016. At the end of first
quarter 2017, over 35 ICD waterflood systems have been installed
throughout the Williston Basin and Shaunavon resource plays with
additional installations planned after break-up.

/T/

FINANCIAL HIGHLIGHTS

/T/

— Funds flow from operations totaled $427.1 million, or $0.78 per share

diluted. The Company achieved a payout ratio of 12 percent based on cash
dividends paid of $0.09 per share. Based on 2017 guidance, Crescent
Point expects to generate a total payout ratio of 91 percent at a WTI
price of US$55.00/bbl.
— The Company spent $465.5 million on drilling and development activities
during first quarter, drilling 286 (259.7 net) wells. Approximately
$50.0 million of this capital was allocated to wells that were drilled
but have not yet been completed. Including land, seismic and facilities,
Crescent Point’s total capital expenditures were $532.1 million.
— As part of its risk management program, Crescent Point hedged 3.8
million barrels of oil during first quarter 2017. As at April 24, 2017,
41 percent of the Company’s remaining 2017 oil production, net of
royalty interest, is hedged at a weighted average market value price of
approximately CDN$71.00/bbl. For the first half of 2018, 13 percent of
oil production is hedged at a weighted average market value price of
approximately CDN$73.00/bbl. Crescent Point also has a significant
amount of its natural gas production hedged through 2019 at a weighted
average price of CDN$2.87/GJ.
— During the quarter, the Company completed an acquisition of
approximately 8,500 net acres in North Dakota for a total cash
consideration of US$100.0 million. The acquired lands are contiguous to
Crescent Point’s current acreage and provide strong future growth
opportunities with approximately 50 net high-quality drilling locations.
During the quarter, the Company also entered into an agreement to
dispose of 1,100 boe/d of non-operated conventional assets in Manitoba
for cash proceeds of $93.2 million. This transaction is expected to
close during second quarter 2017.
— Crescent Point retains a significant amount of liquidity and financial
flexibility with no material near-term debt maturities. The Company’s
covenant-based, unsecured credit facility had unutilized credit capacity
of approximately $1.45 billion as at March 31, 2017, not reflecting the
asset disposition expected to be completed subsequent to first quarter.

/T/

OUTLOOK

Crescent Point’s strong first quarter results position the Company to meet or
exceed its 2017 production guidance, which is expected to be revisited
following spring break-up.

Crescent Point remains focused on executing its organic growth plan, advancing
its new play development and implementing new technologies such as its ICD
waterflood system. The Company continues to explore additional disposition
opportunities with potential proceeds to be redeployed toward debt reduction or
additional growth opportunities.

“We are currently ahead of our budget and targeting exit to exit growth of 10
percent per share in 2017,” said Saxberg. “With WTI prices in the mid-US$50
range, we expect to generate a total payout ratio of approximately 91 percent.”

Crescent Point’s technical expertise and success in applying new technologies
remains one of the Company’s many differentiating factors that continues to
drive its success. Since inception, the Company has drilled approximately 5,000
horizontal wells and applied numerous technologies within its drilling,
completions and waterflood programs. This in-house knowledge and accompanying
large data set has accelerated the development of Crescent Point’s resource
plays, including its earlier stage assets in Canada and the United States.

“Crescent Point’s success and solid operational results over the past 16 years
are a product of the culture and values promoted throughout the organization,”
said Saxberg. “We focus on creating long-term shareholder value through
technological innovation, financial discipline, strong corporate governance,
employee and community wellness, environmental stewardship and the promotion of
health and safety.”

In early May 2017, the Company will host a technical day for investors. This
event is expected to provide greater insight into Crescent Point’s assets,
including its new play development, technical expertise and long-term growth
plans.

OPERATIONS REVIEW

First Quarter Operations Highlights and Summary

In first quarter 2017, the Company continued to execute its long-term growth
strategy through the development of high-quality, long-life, light and medium
oil weighted properties.

The drilling efficiencies that Crescent Point realized in 2016 continued into
first quarter 2017. Capital costs on average remained relatively unchanged in
comparison to year-end 2016.

Drilling Results

The following table summarizes Crescent Point’s drilling results for the three
months ended March 31, 2017:

/T/

—————————————————————————-
Three months ended March 31, 2017 Gas Oil D&A Service
—————————————————————————-
Williston Basin (1) – 159 – –
Southwest Saskatchewan – 106 – –
Uinta Basin (1) – 14 – –
Other – 7 – –
—————————————————————————-
Total – 286 – –
—————————————————————————-

—————————————————————————-
Three months ended March 31, 2017 Standing Total Net % Success
—————————————————————————-
Williston Basin (1) – 159 141.2 100
Southwest Saskatchewan – 106 103.6 100
Uinta Basin (1) – 14 8.2 100
Other – 7 6.7 100
—————————————————————————-
Total – 286 259.7 100
—————————————————————————-
(1) The net well count is subject to final working interest determination

/T/

Williston Basin

During first quarter, the Company drilled 159 (141.2 net) oil wells in the
Williston Basin. Crescent Point’s development strategy continues to include a
combination of low-risk, high-return infill development, step-out drilling to
expand economic boundaries and down-spacing to identify new drilling locations.
The Company’s 2017 step-out program includes the continued expansion of the
North Dakota Three Forks resource play across the Canadian border. The program
has successfully grown this resource play in multiple directions and continues
to advance with the implementation of new completion fluids.

Southwest Saskatchewan

Crescent Point drilled 106 (103.6 net) oil wells during first quarter in
southwest Saskatchewan. The Company’s development strategy focused on low-risk,
high-return infill development in the Shaunavon resource play and the continued
testing of its extended reach horizontal program in the Viking resource play.
Crescent Point is encouraged by the results of its extended reach program,
which provide the potential for additional drilling locations and improved play
economics.

As part of its 2017 budget, the Company plans to construct new infrastructure
in the Shaunavon area, including a new gas plant to accommodate production
growth. Such investments are expected to continue to reduce Crescent Point’s
operating expenses.

Uinta Basin

During first quarter, the Company increased its horizontal inventory in the
Castle Peak zone by internally identifying 80 net new locations based on
successful production results, additional core work and refined mapping.
Crescent Point’s total Castle Peak horizontal inventory now totals
approximately 200 net wells based on spacing of four one-mile wells per section.

The Company continued to advance its Castle Peak horizontal program by drilling
four net horizontal wells during first quarter. Production results from wells
drilled and completed to date continue to support Crescent Point’s horizontal
Castle Peak type curve, which is expected to generate a 90-day initial
production rate of approximately 650 boe/d.

The Company plans for further expansion of the play with improved efficiencies
by testing longer lateral wells, increased stage counts and tonnage per stage,
down-spacing and drilling in other zones beyond the Castle Peak.

WATERFLOOD UPDATE

Crescent Point’s waterflood strategy during 2017 focuses on the continued
implementation and testing of its ICD waterflood system, which increased water
injectivity in its initial pilot during late 2016.

At the end of first quarter, the Company has installed over 35 ICD waterflood
systems in its Williston Basin and Shaunavon resource plays with additional
installations planned after break-up. Results from these installations are
being monitored throughout the year.

Increased water injectivity and enhanced water distribution is expected to help
manage reservoir pressure to improve decline rates and estimated ultimate
recoveries. Favourable results provide Crescent Point with the opportunity to
transition approximately 270 existing injection wells to the new ICD waterflood
system without having to take existing producing wells offline.

The Company continues to advance the unitization of its four initial units in
the Bakken waterflood. Crescent Point has also identified additional units
within the Viewfield Bakken for future waterflood expansion.

ACQUISITIONS AND DISPOSITIONS

During first quarter, the Company acquired approximately 8,500 net acres
contiguous to its core assets in Williams County, North Dakota for a total cash
consideration of US$100.0 million. The assets have a high working interest of
76 percent and are primarily undeveloped with approximately 50 net high-quality
internally identified drilling locations. This provides Crescent Point with
future investment opportunities of approximately US$250 million based on
current well costs. The acquired assets are entirely held by production and
currently produce approximately 375 boe/d.

Over the last two years, the Company has successfully advanced its North Dakota
resource play through down-spacing programs, lower costs, faster drilling days
and increasing efficiencies from multi-well pad drilling.

During the quarter, Crescent Point entered into an agreement to dispose of
1,100 boe/d of non-operated conventional assets in Manitoba for cash proceeds
of $93.2 million. This transaction is expected to close during second quarter
2017, with proceeds to be directed toward debt reduction.

The Company remains focused on executing its organic growth plan in 2017, which
is expected to deliver exit production growth of 10 percent per share. Crescent
Point continues to explore disposition opportunities within its asset base with
potential proceeds to be redeployed toward debt reduction or to fund any
additional potential growth opportunities.

CONFERENCE CALL DETAILS

Crescent Point management will host a conference call on Thursday, April 27,
2017 at 10:00 a.m. MT (12:00 p.m. ET), to discuss the results and outlook for
the Company.

Participants can access the conference call by dialing 844-231-0101 or
216-562-0389. Alternatively, to listen to this event online, please enter
http://edge.media-server.com/m/p/ihfs4jr6 into any web browser.

For those unable to participate in the conference call at the scheduled time,
it will be archived for replay. The replay can be accessed by dialing
855-859-2056 or 404-537-3406 and entering the passcode 94659266. The replay
will be available approximately one hour following completion of the call. The
webcast will be archived on Crescent Point’s website at
www.crescentpointenergy.com.

Shareholders and investors can also find Crescent Point’s most recent investor
presentation on the Company’s website.

2017 GUIDANCE

The Company’s guidance for 2017 is as follows:

/T/

—————————————————————————-
Production

Oil and NGLs (bbls/d) 154,000
Natural gas (mcf/d) 108,000
—————————————————————————-
Total average annual production (boe/d) 172,000
—————————————————————————-
Exit production (boe/d) 183,000
—————————————————————————-
Capital expenditures (1)
Drilling and development ($ millions) $1,290
Facilities and seismic ($ millions) $160
—————————————————————————-
Total ($ millions) $1,450
—————————————————————————-
(1) The projection of capital expenditures excludes property and land
acquisitions, which are separately considered and evaluated.

/T/

ON BEHALF OF THE BOARD OF DIRECTORS

Scott Saxberg
President and Chief Executive Officer
April 27, 2017

The Company’s unaudited financial statements and management’s discussion and
analysis for the quarter ended March 31, 2017, are available on the System for
Electronic Document Analysis and Retrieval (“SEDAR”) at www.sedar.com, on EDGAR
at www.sec.gov/edgar.shtml and on Crescent Point’s website at
www.crescentpointenergy.com.

FINANCIAL AND OPERATING HIGHLIGHTS

/T/

—————————————————————————-

Three months ended
March 31
————————
(Cdn$ millions except per share and per boe amounts) 2017 2016
—————————————————————————-
Financial
Cash flow from operating activities 416.2 328.1
Funds flow from operations (1) 427.1 378.0
Per share (2) 0.78 0.74
Net income (loss) 119.4 (87.5)
Per share (2) 0.22 (0.17)
Adjusted net earnings (loss) from operations (1) 61.9 (5.2)
Per share (1) (2) 0.11 (0.01)
Dividends declared 49.4 117.9
Per share (2) 0.09 0.23
Payout ratio (%) (1) 12 31
Net debt (1) 3,984.7 4,322.4
Net debt to funds flow from operations (1) (3) 2.5 2.3
Decommissioning and environmental expenditures (4) 9.3 10.8
Weighted average shares outstanding
Basic 544.5 505.7
Diluted 546.2 507.6
—————————————————————————-
Operating
Average daily production
Crude oil (bbls/d) 139,303 143,971
NGLs (bbls/d) 17,061 16,775
Natural gas (mcf/d) 101,791 104,972
—————————————————————————-
Total (boe/d) 173,329 178,241
—————————————————————————-
Average selling prices (5)
Crude oil ($/bbl) 59.02 36.27
NGLs ($/bbl) 25.19 8.49
Natural gas ($/mcf) 3.05 2.04
—————————————————————————-
Total ($/boe) 51.70 31.29
—————————————————————————-
Netback ($/boe)
Oil and gas sales 51.70 31.29
Royalties (7.29) (4.45)
Operating expenses (11.89) (10.21)
Transportation expenses (2.12) (2.22)
—————————————————————————-
Netback before hedging 30.40 14.41
Realized gain on derivatives 0.69 13.08
—————————————————————————-
Netback (1) 31.09 27.49
—————————————————————————-
Capital Expenditures
Capital acquisitions (net) (6) 137.5 8.6
Development capital expenditures (4)
Drilling and development 465.5 269.2
Facilities and seismic 53.8 43.1
Land 12.8 9.5
—————————————————————————-
Total 532.1 321.8
—————————————————————————-

/T/

(1) Funds flow from operations, adjusted net earnings from operations,
payout ratio, net debt, net debt to funds flow from operations and netback
as presented do not have any standardized meaning prescribed by IFRS and,
therefore, may not be comparable with the calculation of similar measures
presented by other entities.
(2) The per share amounts (with the exception of dividends per share) are
the per share – diluted amounts.
(3) Net debt to funds flow from operations is calculated as the period end
net debt divided by the sum of funds flow from operations for the trailing
four quarters.
(4) Decommissioning and environmental expenditures includes environmental
emission reduction expenditures, which are also included in development
capital expenditures in the table above.
(5) The average selling prices reported are before realized derivatives.
(6) Capital acquisitions represent total consideration for the transactions,
including long-term debt and working capital assumed, and exclude
transaction costs.

/T/

Non-GAAP Financial Measures

Throughout this press release, the Company uses the terms “funds flow from
operations”, “funds flow from operations per share – diluted”, “adjusted net
earnings from operations”, “adjusted net earnings from operations per share –
diluted”, “net debt”, “net debt to funds flow from operations”, “netback”,
“payout ratio” and “total payout ratio”. These terms do not have any
standardized meaning as prescribed by IFRS and, therefore, may not be
comparable with the calculation of similar measures presented by other issuers.

Funds flow from operations is calculated based on cash flow from operating
activities before changes in non-cash working capital, transaction costs and
decommissioning expenditures. Funds flow from operations per share – diluted is
calculated as funds flow from operations divided by the number of weighted
average diluted shares outstanding. Transaction costs are excluded as they vary
based on the Company’s acquisition activity, and to ensure that this metric is
more comparable between periods. Decommissioning expenditures are excluded as
the Company has a voluntary reclamation fund to fund decommissioning costs.
Management utilizes funds flow from operations as a key measure to assess the
ability of the Company to finance dividends, operating activities, capital
expenditures and debt repayments. Funds flow from operations as presented is
not intended to represent cash flow from operating activities, net earnings or
other measures of financial performance calculated in accordance with IFRS.

The following table reconciles cash flow from operating activities to funds
flow from operations:

/T/

—————————————————————————-

Three months ended
March 31
($ millions) 2017 2016
—————————————————————————-
Cash flow from operating activities 416.2 328.1
Changes in non-cash working capital 1.6 45.3
Transaction costs 0.5 0.3
Decommissioning expenditures 8.8 4.3
—————————————————————————-
Funds flow from operations 427.1 378.0
—————————————————————————-

/T/

Adjusted net earnings from operations is calculated based on net income before
amortization of exploration and evaluation (“E&E”) undeveloped land, impairment
or impairment recoveries on property, plant and equipment (“PP&E”), unrealized
derivative gains or losses, unrealized foreign exchange gain or loss on
translation of hedged US dollar long-term debt, unrealized gains or losses on
long-term investments and gains or losses on capital acquisitions and
dispositions. Adjusted net earnings from operations per share – diluted is
calculated as adjusted net earnings from operations divided by the number of
weighted average diluted shares outstanding. Management utilizes adjusted net
earnings from operations to present a measure of financial performance that is
more comparable between periods. Adjusted net earnings from operations as
presented is not intended to represent net earnings or other measures of
financial performance calculated in accordance with IFRS.

The following table reconciles net income to adjusted net earnings from
operations:

/T/

—————————————————————————-

Three months ended
March 31
($ millions) 2017 2016
—————————————————————————-
Net income (loss) 119.4 (87.5)
Amortization of E&E undeveloped land 31.0 50.3
Unrealized derivative (gains) losses (89.1) 298.6
Unrealized foreign exchange gain on translation of
hedged US dollar long-term debt (22.9) (230.5)
Unrealized (gain) loss on long-term investments 3.2 (2.1)
Deferred tax relating to adjustments 20.3 (34.0)
—————————————————————————-
Adjusted net earnings (loss) from operations 61.9 (5.2)
—————————————————————————-

/T/

Net debt is calculated as long-term debt plus accounts payable and accrued
liabilities and dividends payable, less cash, accounts receivable, prepaids and
deposits and long-term investments, excluding the unrealized foreign exchange
on translation of hedged US dollar long-term debt. Management utilizes net debt
as a key measure to assess the liquidity of the Company.

The following table reconciles long-term debt to net debt:

/T/

—————————————————————————-
($ millions) March 31, 2017 March 31, 2016
—————————————————————————-
Long-term debt (1) 4,183.4 4,444.8
Accounts payable and accrued liabilities 642.1 499.2
Dividends payable 16.5 15.2
Cash (85.8) (25.1)
Accounts receivable (330.3) (269.0)
Prepaids and deposits (10.9) (9.6)
Long-term investments (32.6) (32.4)
Excludes:
Unrealized foreign exchange on translation
of hedged US dollar long-term debt (397.7) (300.7)
—————————————————————————-
Net debt 3,984.7 4,322.4
—————————————————————————-
(1) Includes current portion of long-term debt.

/T/

Net debt to funds flow from operations is calculated as the period end net debt
divided by the sum of funds flow from operations for the trailing four
quarters. The ratio of net debt to funds flow from operations is used by
management to measure the Company’s overall debt position and to measure the
strength of the Company’s balance sheet. Crescent Point monitors this ratio and
uses this as a key measure in making decisions regarding financing, capital
spending and dividend levels.

Netback is calculated on a per boe basis as oil and gas sales, less royalties,
operating and transportation expenses and realized derivative gains and losses.
Netback is a common metric used in the oil and gas industry and is used by
management to measure operating results on a per boe basis to better analyze
performance against prior periods on a comparable basis. The calculation of
netback is shown in the Financial and Operating Highlights section in this
press release.

Payout ratio is calculated on a percentage basis as dividends declared divided
by funds flow from operations. Payout ratio is used by management to monitor
the dividend policy and the amount of funds flow from operations retained by
the Company for capital reinvestment.

Total payout ratio is calculated on a percentage basis as development capital
expenditures and dividends declared divided by funds flow from operations.
Total payout ratio is used by management to monitor the Company’s capital
reinvestment and dividend policy, as a percentage of the amount of funds flow
from operations.

Management believes the presentation of the Non-GAAP measures above provide
useful information to investors and shareholders as the measures provide
increased transparency and the ability to better analyze performance against
prior periods on a comparable basis.

Forward-Looking Statements and Other Matters

Any “financial outlook” or “future oriented financial information” in this
press release, as defined by applicable securities legislation has been
approved by management of Crescent Point. Such financial outlook or future
oriented financial information is provided for the purpose of providing
information about management’s current expectations and plans relating to the
future. Readers are cautioned that reliance on such information may not be
appropriate for other purposes.

Certain statements contained in this press release constitute “forward-looking
statements” within the meaning of section 27A of the Securities Act of 1933 and
section 21E of the Securities Exchange Act of 1934 and “forward-looking
information” for the purposes of Canadian securities regulation (collectively,
“forward-looking statements”). The Company has tried to identify such
forward-looking statements by use of such words as “could”, “should”, “can”,
“anticipate”, “expect”, “believe”, “will”, “may”, “intend”, “projected”,
“sustain”, “continues”, “strategy”, “potential”, “projects”, “grow”, “take
advantage”, “estimate”, “well-positioned” and other similar expressions, but
these words are not the exclusive means of identifying such statements.

In particular, this press release contains forward-looking statements
pertaining, among other things, to the following: the Company’s focus on
organic growth and targeting exit to exit production growth of 10 percent per
share; continued expansion of the Uinta Basin play by testing increased lateral
lengths, increased stages and tonnage per stage, down-spacing and targeting
additional zones beyond Castle Peak; Crescent Point’s areas of focus and
drilling inventory in the Williston Basin; the Company’s plans to continue to
advance its ICD waterflood systems, including planned installations following
break-up; the Company’s estimated total payout ratio in 2017 at WTI prices in
the mid-US$50 range; the potential growth associated with 8,500 net acres
acquired in North Dakota; the expected closing time for the sale of Manitoba
assets; the positioning of the Company to meet or exceed its 2017 production
guidance; the Company’s plans to revisit its production guidance following
spring break-up; the Company’s plans to continue to explore additional non-core
disposition opportunities within its assets base and the potential uses for the
proceeds therefrom; the Company’s plan to hold a technical day for investors in
May 2017 to provide greater insight into the Company’s largest core assets; the
Company’s development strategies for the Williston Basin, Southwest
Saskatchewan and the Uinta Basin; new infrastructure plans in the Shaunavon
area and the expected impact such plans will have on operating expenses; the
expected results the Company’s Castle Peak horizontal program, the horizontal
Castle Peak type curve and the expected 90-day initial production rate of such
wells; plans to further expand the Uinta Basin play with improved efficiencies
and how such efficiencies are expected to be achieved; the Company’s 2017
waterflood strategy; the Company’s expectation that production results from
newly installed ICD waterflood systems will be monitored throughout the year;
the expectation that increased water injectivity and enhanced water
distribution will help manage reservoir pressure to improve decline rates and
estimated ultimate recoveries; the investment opportunities associated with the
Company’s first quarter North Dakota acquisition based on current well costs;
the expected use of the proceeds from the disposition of assets in Manitoba;
the expectation that using the ICD waterflood technology will allow existing
injectors to become candidates for additional injector conversions without the
need to take existing producing wells offline; and the Company’s guidance for
2017.

Approximately 200 net Castle Peak horizontal locations are internally
identified, of which approximately 13 net are proved and probable locations as
independently evaluated by GLJ Petroleum Consultants Limited as of December 31,
2016. The remaining net locations are internally identified locations that are
unbooked. Approximately 80 net new Castle Peak horizontal locations were
internally identified during first quarter 2017, all of which are currently
unbooked. Approximately 50 net locations in Williams County, ND are internally
identified, of which approximately 10 net are proved locations as independently
evaluated by GLJ Petroleum Consultants Ltd. as of January 31, 2017.

All forward-looking statements are based on Crescent Point’s beliefs and
assumptions based on information available at the time the assumption was made.
Crescent Point believes that the expectations reflected in these
forward-looking statements are reasonable but no assurance can be given that
these expectations will prove to be correct and such forward-looking statements
included in this report should not be unduly relied upon. By their nature, such
forward-looking statements are subject to a number of risks, uncertainties and
assumptions, which could cause actual results or other expectations to differ
materially from those anticipated, expressed or implied by such statements,
including those material risks discussed in the Company’s Annual Information
Form for the year ended December 31, 2016 under “Risk Factors,” in our
Management’s Discussion and Analysis for the year ended December 31, 2016,
under the headings “Risk Factors” and “Forward-Looking Information” and for the
quarter ended March 31, 2017 under “Derivatives”, “Liquidity and Capital
Resources”, “Changes in Accounting Policy” and “Outlook”. The material
assumptions are disclosed in the Management’s Discussion and Analysis for the
year ended December 31, 2016, under the headings “Capital Expenditures”,
“Liquidity and Capital Resources”, “Critical Accounting Estimates”, “Risk
Factors”, “Changes in Accounting Policies” and “Outlook” and are disclosed in
the Management’s Discussion and Analysis for the quarter ended March 31, 2017
under the headings “Derivatives”,
“Liquidity and Capital Resources”, “Changes in Accounting Policy” and
“Outlook”. In addition, risk factors include: financial risk of marketing
reserves at an acceptable price given market conditions; volatility in market
prices for oil and natural gas; delays in business operations, pipeline
restrictions, blowouts; the risk of carrying out operations with minimal
environmental impact; industry conditions including changes in laws and
regulations and the adoption of new environmental laws and regulations and
changes in how they are interpreted and enforced; risks and uncertainties
related to all oil and gas interests and operations on tribal lands;
uncertainties associated with estimating oil and natural gas reserves; economic
risk of finding and producing reserves at a reasonable cost; uncertainties
associated with partner plans and approvals; operational matters related to
non-operated properties; increased competition for, among other things,
capital, acquisitions of reserves and undeveloped lands; competition for and
availability of qualified personnel or management; incorrect assessments of the
value of acquisitions and exploration and development programs; unexpected
geological, technical, drilling, construction and processing problems;
availability of insurance; fluctuations in foreign exchange and interest rates;
stock market volatility; failure to realize the anticipated benefits of
acquisitions; general economic, market and business conditions; uncertainties
associated with regulatory approvals; uncertainty of government policy changes;
uncertainties associated with credit facilities and counterparty credit risk;
and changes in income tax laws, tax laws, crown royalty rates and incentive
programs relating to the oil and gas industry; and other factors, many of which
are outside the control of Crescent Point. The impact of any one risk,
uncertainty or factor on a particular forward-looking statement is not
determinable with certainty as these are interdependent and Crescent Point’s
future course of action depends on management’s assessment of all information
available at the relevant time.

Additional information on these and other factors that could affect Crescent
Point’s operations or financial results are included in Crescent Point’s
reports on file with Canadian and U.S. securities regulatory authorities.
Readers are cautioned not to place undue reliance on this forward-looking
information, which is given as of the date it is expressed herein or otherwise.
Crescent Point undertakes no obligation to update publicly or revise any
forward-looking statements, whether as a result of new information, future
events or otherwise, unless required to do so pursuant to applicable law. All
subsequent forward-looking statements, whether written or oral, attributable to
Crescent Point or persons acting on the Company’s behalf are expressly
qualified in their entirety by these cautionary statements.

Crescent Point shares are traded on the Toronto Stock Exchange and New York
Stock Exchange under the symbol CPG.

Crescent Point Energy Corp.
Suite 2000, 585 – 8th Avenue S.W.
Calgary, Alberta T2P 1G1

– END RELEASE – 27/04/2017

For further information:
Crescent Point Energy Corp.
Ken Lamont
Chief Financial Officer
(403) 693-0020 or Toll-free (US & Canada): 888-693-0020
OR
Crescent Point Energy Corp.
Brad Borggard
Vice President, Corporate Planning and Investor Relations
(403) 693-0020 or Toll-free (US & Canada): 888-693-0020
(403) 693-0070 (FAX)
www.crescentpointenergy.com

COMPANY:
FOR: CRESCENT POINT ENERGY CORP.
TSX SYMBOL: CPG
NYSE SYMBOL: CPG

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170427CC0009

Press Release from Marketwired 1-866-736-3779

Date of Board Meeting

April 27, 2017 by The Canadian Press

FOR: SUNSHINE OILSANDS LTD.HKSE SYMBOL: 2012Date issue: April 27, 2017Time in: 6:07 AM eAttention:
HONG KONG, CHINA and CALGARY, ALBERTA–(Marketwired – April 27, 2017) – The
board of directors (the “Board”) of Sunshine Oilsands Ltd. (HKSE:2012) (the
…

Leucrotta Announces Q4 2016 Financial and Operating Results

April 27, 2017 by The Canadian Press

FOR: LEUCROTTA EXPLORATION INC.
TSX VENTURE SYMBOL: LXE

Date issue: April 27, 2017
Time in: 6:00 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 27, 2017) – LEUCROTTA EXPLORATION INC.
(TSX VENTURE:LXE) (“Leucrotta” or the “Company”) is pleased to announce its
financial and operating results for the three months and year ended December
31, 2016. All dollar figures are Canadian dollars unless otherwise noted.

HIGHLIGHTS

/T/

— Materially extended the mapping and productive boundaries of the Lower

Montney Turbidite Light Oil Resource Play with the drilling of three
delineation wells (two horizontal and one vertical).

— Expanded pipeline/infrastructure system in Q4 2016 and into Q1 2017 with

four previously drilled wells being put on-stream in Q1 2017.

— Maintained a cash and working capital balance of $26.1 million at

December 31, 2016.

— Subsequent to year-end entered into a purchase and sale agreement to

acquire certain lands located within the Company’s core Doe/Mica area
for an aggregate cash purchase price of approximately $36.0 million. The
acquisition is expected to close on or about May 31, 2017.

— Subsequent to year-end entered into an agreement with a syndicate of

underwriters with respect to an offering of common shares and flow-
through common shares by way of a short form prospectus for gross
proceeds of $80.0 million (the “Offering”). The Offering is for an
aggregate of 33,333,400 common shares at a price of $2.25 per common
share and 1,852,000 common shares on a flow-through basis at a price of
$2.70 per flow-through common share, closing on April 26, 2017.

Three Months Ended December 31 Year Ended December 31
($000s, except per
share amounts) 2016 2015 % Change 2016 2015% Change
—————————————————————————

Oil and natural
gas sales 2,281 2,819 (19) 8,844 10,859 (19)

Funds (used in)
from operations
(1) (98) 464 (121) (996) 615 (262)
Per share – basic
and diluted – – – (0.01) – (100)

Net (loss)
earnings (1,657) (15,205) (89) (12,182) 11,412 (207)
Per share – basic
and diluted (0.01) (0.09) (89) (0.07) 0.07 (200)

Capital
expenditures and
acquisitions 11,718 29,544 (60) 22,574 59,237 (62)

Proceeds from:
Property

dispositions – – – – 79,342 (100)
Sale of gas plant
equipment – – – 4,000 – 100

Working capital 26,063 45,633 (43)

Common shares
outstanding
(000s)
Weighted average

– basic and
diluted 165,227 165,227 – 165,227 165,227 –

End of period –

basic 165,227 165,227 –
End of period –
diluted 189,297 189,272 –
—————————————————————————

/T/

(1) See “Non-GAAP Measures” section.

/T/

OPERATING RESULTS
(1) Three Months Ended December 31 Year Ended December 31
2016 2015 % Change 2016 2015 % Change
—————————————————————————

Daily production
Oil and NGLs

(bbls/d) 234 479 (51) 317 316 –
Natural gas
(mcf/d) 3,543 3,585 (1) 4,325 6,112 (29)
—————————————————————————
Oil equivalent
(boe/d) 824 1,076 (23) 1,038 1,335 (22)

Revenue
Oil and NGLs

($/bbl) 53.60 46.85 14 45.04 45.74 (2)
Natural gas
($/mcf) 3.46 2.29 51 2.30 2.50 (8)
—————————————————————————
Oil equivalent
($/boe) 30.08 28.47 6 23.35 22.29 5

Royalties
Oil and NGLs

($/bbl) 6.99 8.90 (21) 4.69 6.91 (32)
Natural gas
($/mcf) 0.16 0.12 33 0.06 0.08 (25)
—————————————————————————
Oil equivalent
($/boe) 2.68 4.37 (39) 1.67 1.98 (16)

Production
expenses
Oil and NGLs

($/bbl) 26.24 16.58 58 18.52 12.58 47
Natural gas
($/mcf) 1.76 0.96 83 1.27 1.16 9
—————————————————————————
Oil equivalent
($/boe) 15.02 10.56 42 10.96 8.29 32

Transportation
expenses
Oil and NGLs

($/bbl) 6.04 5.35 13 5.24 4.54 15
Natural gas
($/mcf) 0.47 0.32 47 0.44 0.30 47
—————————————————————————
Oil equivalent
($/boe) 3.71 3.46 7 3.43 2.47 39

Operating netback
(2)
Oil and NGLs

($/bbl) 14.33 16.02 (11) 16.59 21.71 (24)
Natural gas
($/mcf) 1.07 0.89 20 0.53 0.96 (45)
—————————————————————————
Oil equivalent
($/boe) 8.67 10.08 (14) 7.29 9.55 (24)

Depletion and
depreciation
($/boe) (13.07) (52.91) (75) (13.07) (17.67) (26)
Asset impairment
($/boe) – (83.53) (100) – (18.91) (100)
General and
administrative
expenses ($/boe) (11.08) (7.50) 48 (11.11) (9.46) 17
Share based
compensation
($/boe) (7.11) (10.82) (34) (9.36) (11.02) (15)
Finance expenses
($/boe) (0.81) (0.46) 76 (0.49) (0.49) –
Finance income
($/boe) 1.54 2.26 (32) 1.35 1.38 (2)
Loss (gain) on
sale of assets
($/boe) – (3.35) (100) (6.77) 93.19 (107)
Deferred tax
expense ($/boe) – (7.28) (100) – (23.14) (100)
—————————————————————————
Net (loss)
earnings ($/boe) (21.86) (153.51) (86) (32.16) 23.43 (237)
—————————————————————————
—————————————————————————

/T/

(1) See “Frequently Recurring Terms” section.

(2) See “Non-GAAP Measures” section.

Selected financial and operational information outlined in this news release
should be read in conjunction with Leucrotta’s audited financial statements and
related Management’s Discussion and Analysis (“MD&A”) for the year ended
December 31, 2016, which are available on SEDAR at www.sedar.com.

PRESIDENT’S MESSAGE

In Q4 2016 and early Q1 2017, Leucrotta completed its infrastructure project to
tie-in four previously drilled delineation wells and has drilled three
additional step-out/delineation wells that materially extend the productive
boundaries of the Company’s Lower Montney Turbidite Light Oil Resource Play.

As a result of the tie-in of four wells, Leucrotta increased production to over
3,000 boe/d (25% oil and NGLs). This excludes two new Montney wells (8-4 and
12-06) that are tested but not tied-in and one well (13-07) that is temporarily
shut-in due to third party restrictions.

The three step-out/delineation wells materially extended the productive
boundaries of the Lower Montney Turbidite Light Oil Resource Play. The 8-4 well
was drilled 5.2 km north and west of the previously drilled 8-22 well. The well
encountered light oil in the Lower Montney Turbidite zone and was tested over a
7-day period with an average production of 1,060 boe/d(1). The 12-06 well was
drilled 11.7 kms south of the 13-07 oil well and 4.4 kms north of the 13-19
liquids-rich gas well. The well encountered oil pay and was tested over a 7-day
period with average production of 550 boe/d(1). The third step-out /delineation
well was a vertical stratigraphic test drilled at 4-30 north of the Peace
River. Located 7.4 km northwest of the 8-4 well, the well was logged and cored
in the Upper, Middle and Lower Montney. The well encountered 55 metres of pay
in the Lower Montney with core porosities on par with the core porosities in
the 13-7 well. The 4-30 vertical well confirms the geological mapping and oil
charge of a major northern extension of the Lower Montney Turbidite Light Oil
Resource Play. Analysis of Upper and Middle Montney in the 4-30 wellbore showed
potential as exploratory future targets.

Subsequent to year-end, Leucrotta signed agreements to acquire an additional
18.5 sections of land located in its core Doe/Mica Montney area and initiated a
bought-deal financing for gross proceeds of $80 million to fund the acquisition
and a portion of the future capital programs. Leucrotta has estimated that it
will have approximately $50 million of cash and no debt on completion of the
financing and funding the land acquisitions.

On a go forward basis, Leucrotta will continue its capital program focused
primarily on the delineation and development of its Doe/Mica core area.

(1) See “Test Results and Production Rates” section.

FREQUENTLY RECURRING TERMS

The Company uses the following frequently recurring industry terms in this news
release: “bbls” refers to barrels, “mcf” refers to thousand cubic feet, and
“boe” refers to barrel of oil equivalent. Disclosure provided herein in respect
of a boe may be misleading, particularly if used in isolation. A boe conversion
rate of six thousand cubic feet of natural gas to one barrel of oil equivalent
has been used for the calculation of boe amounts in this news release. This boe
conversion rate is based on an energy equivalency conversion method primarily
applicable at the burner tip and does not represent a value equivalency at the
wellhead.

NON-GAAP MEASURES

This news release refers to certain financial measures that are not determined
in accordance with IFRS (or “GAAP”). This news release contains the terms
“funds from (used in) operations”, “funds from (used in) operations per share”,
and “operating netback” which do not have any standardized meaning prescribed
by GAAP and therefore may not be comparable to similar measures used by other
companies. The Company uses these measures to help evaluate its performance.

Management uses funds from (used in) operations to analyze performance and
considers it a key measure as it demonstrates the Company’s ability to generate
the cash necessary to fund future capital investments and to repay debt. Funds
from (used in) operations is a non-GAAP measure and has been defined by the
Company as cash flow from (used in) operating activities excluding the change
in non-cash working capital related to operating activities and expenditures on
decommissioning obligations. The Company also presents funds from (used in)
operations per share whereby amounts per share are calculated using weighted
average shares outstanding, consistent with the calculation of earnings (loss)
per share. Funds from (used in) operations is reconciled from cash flow from
(used in) operating activities under the heading “Funds from (used in)
Operations” in the Company’s MD&A for the year ended December 31, 2016, which
is available on SEDAR at www.sedar.com.

Management considers operating netback an important measure as it demonstrates
its profitability relative to current commodity prices. Operating netback,
which is calculated as average unit sales price less royalties, production
expenses, and transportation expenses, represents the cash margin for every
barrel of oil equivalent sold. Operating netback per boe is reconciled to net
loss per boe under the heading “Operating Netback” in the Company’s MD&A for
the year ended December 31, 2016, which is available on SEDAR at www.sedar.com.

TEST RESULTS AND PRODUCTION RATES

The 8-4-82-14W6 well was production tested for 7 days after the original
cleanup and produced at an average rate of 1,060 boe/d (50% gas, 50% Oil and
Condensate) over that period, excluding load fluid and energizing fluid. At the
end of the test, flowing wellhead pressure and production rates were stable.

The 12-6-81-13W6 well was production tested for 7 days after the original
cleanup and produced at an average rate of 550 boe/d (60% gas, 40% Oil and
Condensate) over that period, excluding load fluid and energizing fluid. At the
end of the test, flowing wellhead pressure and production rates were stable.

A pressure transient analysis or well-test has not been carried out on these
wells and thus certain of the test results provided herein should be considered
to be preliminary until such analysis or interpretation has been completed.
Test results and initial production rates disclosed herein may not necessarily
be indicative of long term performance or of ultimate recovery.

FORWARD-LOOKING INFORMATION

This news release contains forward-looking statements and forward-looking
information within the meaning of applicable securities laws. The use of any of
the words “expect”, “anticipate”, “continue”, “estimate”, “may”, “will”,
“should”, “believe”, “intends”, “forecast”, “plans”, “guidance” and similar
expressions are intended to identify forward-looking statements or information.

More particularly and without limitation, this news release contains forward
looking statements and information relating to the Company’s oil, NGLs, and
natural gas production, capital programs, and working capital. The
forward-looking statements and information are based on certain key
expectations and assumptions made by the Company, including expectations and
assumptions relating to prevailing commodity prices and exchange rates,
applicable royalty rates and tax laws, future well production rates, the
performance of existing wells, the success of drilling new wells, the
availability of capital to undertake planned activities, and the availability
and cost of labour and services.

Although the Company believes that the expectations reflected in such
forward-looking statements and information are reasonable, it can give no
assurance that such expectations will prove to be correct. Since
forward-looking statements and information address future events and
conditions, by their very nature they involve inherent risks and uncertainties.
Actual results may differ materially from those currently anticipated due to a
number of factors and risks. These include, but are not limited to, the risks
associated with the oil and gas industry in general such as operational risks
in development, exploration and production, delays or changes in plans with
respect to exploration or development projects or capital expenditures, the
uncertainty of estimates and projections relating to production rates, costs,
and expenses, commodity price and exchange rate fluctuations, marketing and
transportation, environmental risks, competition, the ability to access
sufficient capital from internal and external sources and changes in tax,
royalty, and environmental legislation. The forward-looking statements and
information contained in this document are made as of the date hereof for the
purpose of providing the readers with the Company’s expectations for the coming
year. The forward-looking statements and information may not be appropriate for
other purposes. The Company undertakes no obligation to update publicly or
revise any forward-looking statements or information, whether as a result of
new information, future events or otherwise, unless so required by applicable
securities laws.

Leucrotta is an oil and natural gas company, actively engaged in the
acquisition, development, exploration, and production of oil and natural gas
reserves in northeastern British Columbia, Canada.

– END RELEASE – 27/04/2017

For further information:
Mr. Robert J. Zakresky
President and Chief Executive Officer
(403) 705-4525
OR
Mr. Nolan Chicoine
Vice President, Finance and Chief Financial Officer
(403) 705-4525
OR
Leucrotta Exploration Inc.
Suite 700, 639 – 5th Avenue SW
Calgary, Alberta T2P 0M9
(403) 705-4525
(403) 705-4526 (FAX)

COMPANY:
FOR: LEUCROTTA EXPLORATION INC.
TSX VENTURE SYMBOL: LXE

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170427CC0003

Press Release from Marketwired 1-866-736-3779

Q4 and Year End 2016 Results Published

April 26, 2017 by The Canadian Press

FOR: PETROMAROC CORPORATION PLC
TSX VENTURE SYMBOL: PMA

Date issue: April 27, 2017
Time in: 2:00 AM e

Attention:

TORONTO, ONTARIO–(Marketwired – April 27, 2017) – PetroMaroc Corporation plc
(TSX VENTURE:PMA), an independent oil and gas company focused on Morocco (the
“Company” or “PetroMaroc”) is pleased to announce its financial and operating
results for the year ended December 31, 2016, and the fourth quarter of 2016.

Commenting, D. Campbell Deacon, Chief Executive Officer of PetroMaroc, said:
“During 2016, the Company announced and significantly advanced the binding sale
and purchase agreement with Sound Energy plc (“Sound Energy”). In early January
2017, the Company announced all conditions precedent were successfully
fulfilled with the transaction completing, following which, PetroMaroc’s
consideration shares in Sound Energy enable the Company to be positioned to
leverage off Sound Energy’s operating capability in country and balance sheet
whilst retaining material upside with the Sidi Moktar Net Profit Interests. We
look forward to the near-term testing of Kechoula by Sound Energy – a rig is
being mobilised to Sidi Moktar, and is expected to arrive in May 2017, upon
which, Sound Energy will re-enter and test the two existing wells on the
Kechoula discovery which, subject to initial well results, may include a
side-track and an extended well test thereafter.” “During 2016, the Company
successfully restructured the Cdn $11.09 million principal amount of secured
debentures, which were rolled into a new class of secured redeemable,
debentures, issuable in series, with all principal and interest due and payable
in full on January 31, 2018. Through 2016, monthly general and administrative
costs totalled US$0.14 million, representing a 10% decrease in comparison to
2015 (US$0.16 million) and a 43% decrease in comparison to 2014 (US$0.25
million). During 2016, the Company secured the release of the US$2.5 million
Sidi Moktar bank guarantee restricted cash, disposed of surplus inventory, and
closed a Cdn$0.39 million secured non-convertible debenture financing.”

PetroMaroc exited 2016 with cash of US$2.1 million and a working capital
deficit as at December 31, 2016 of US$0.2 million (excluding the secured
debentures, excluding the secured debenture accrued interest and fees,
excluding the unsecured loan and interest, including restricted cash).

During 2016, the Company carefully reviewed its secured debentures, and equity
capital. In late 2016, following shareholder approval, the Company successfully
restructured the Cdn $11.09 million principal amount of secured debentures (the
“Debentures”), with the Debentures being rolled into a new class of secured
redeemable, debentures, issuable in series, with all principal and interest due
and payable in full on January 31, 2018.

The Company continued its discussions with its Sidi Moktar creditors to
negotiate settlement of the remaining unpaid costs in respect to the Sidi
Moktar drilling campaign. Subsequent to the year-end the Company successfully
executed settlement agreements with a significant proportion of its unsecured
creditors, and the Company continues to engage with the remaining unsecured
creditors to execute settlement agreements.

PetroMaroc today filed its annual financial statements for the year ended
December 31, 2016, together with its Management’s Discussion and Analysis in
respect of the Company’s financial results for the year ended December 31,
2016. These documents are available on the PetroMaroc website at
www.petromaroc.co or under the Company profile on SEDAR at www.sedar.com.

Highlights

Financial:

/T/

— Unrestricted cash as at December 31, 2016, of US$2.1 million (US$0.2

million as at December 31, 2015), US$0.5 million as at September 30,
2016.

— Working capital deficit as at December 31, 2016, US$0.2 million

(excludes the Cdn$11.09 million secured debentures (& excludes Cdn $4.4
million accrued interest and fees as at December 31, 2016) which
maturity date was extended from December 31, 2016 to January 31, 2018,
excludes the Cdn$0.4 million unsecured loan (& accrued interest) which
matured on December 31, 2016, includes US$0.6 million restricted cash).

— Secured full release of the US$2.5 million Sidi Moktar Bank Guarantee

restricted cash in December 2016.

— Closed a Cdn$0.39 million secured debenture financing in June 2016,

bearing interest at 15.0% per annum.

— Disposed of surplus inventory for proceeds of US$0.3 million in February

2016.

— The Company successfully restructured the Cdn $11.09 million principal

amount of secured debentures, with the Debentures being rolled into a
new class of secured redeemable, debentures, issuable in series (the
“New Debentures”), with all principal and interest due and payable in
full on January 31, 2018. The Series 1 New Debentures bear interest at
the rate of 10% per annum and are convertible, at the option of the
holder, into ordinary shares of the Company at a conversion price equal
to $0.06 per share in the first 12 months of the term (January 1, 2017
to December 31, 2017) and $0.10 per share in the last month of the term
(January 1, 2018 to January 31, 2018). The Series 2 New Debentures bear
interest at the rate of 15% per annum, with no right to convert into
ordinary shares of the Company. The Series 1 New Debentures and the
Series 2 New Debentures shall bear an effective issue date of December
31, 2016, being the maturity date of the original Debentures. The Series
1 New Debentures and the Series 2 New Debentures shall rank pari passu
with each other. In accordance with the terms of the New Debentures, the
outstanding accrued interest and fees owing under the Debentures as at
December 31, 2016 has been paid. The outstanding principal amount of the
Series 1 New Debentures is Cdn $4,762,400 and the principal amount owing
under the Series 2 New Debentures is Cdn $6,327,600. The Series 1 New
Debentures are convertible into an aggregate of 79,373,333 ordinary
shares, assuming a conversion price of $0.06 per share.

— Subsequent to the year-end, repaid the Cdn $0.4 million unsecured loan

(& accrued interest) in January 2017.

/T/

— In February 2017, the Company disposed of 5,314,502 Sound Energy shares,

to provide capital to meet its obligations of the Cdn $4,407,056
Debenture accrued interest and fees to the December 31, 2016 maturity
date (Cdn $4,475,878 including the “stub” interest for the period
January 1, 2017 to February 7, 2017 on the Debentures. The proceeds
received (net of transaction costs, and net of proceeds above 50 pence
being allocated equally between the Company and Sound Energy) totaled
GBP 3,841,555 (US $4,739,150).

— Continued to engage with its unsecured creditors from the Sidi Moktar

campaign. Subsequent to the year-end a number of settlement agreements
were successfully executed, with ongoing focus with the residual
unsecured creditors.

/T/

Operations:

/T/

— Sidi Moktar onshore:

— In March 2016, executed a sale and purchase agreement with Sound
energy, with Sound Energy acquiring the Company’s Sidi Moktar
licences in consideration for issuance to the Company 21,258,008
shares of Sound Energy with an estimated market value (at the grant
price of 17.17 pence) of GBP 3.65 million and the Company retaining
a 10% net profit interest in any future cash flows from the Kechoula
structure within the Sidi Moktar licences, and the Company retaining
a 5% net profit interest in any future cash flows from structures
within the Sidi Moktar licences other than the Kechoula structure.
— Subsequent to the year-end, the transaction completed on January 9,
2017 with the Sound Energy shares closing at 75.75 pence per share.
The proceeds from a sale (in whole or in part) of the 21,258,008
Sound Energy ordinary shares will be shared between PetroMaroc and
Sound Energy, with PetroMaroc receiving all proceeds from sale(s) up
to 50 pence per consideration share, and sale proceeds in excess of
50 pence per consideration share will be shared equally between
PetroMaroc and Sound Energy.

— Zag onshore:

— The Company committed to its percentage share of further geophysical
studies and the drilling of one exploration well, subject to
receiving and approving a satisfactory proposal from San Leon
Morocco Limited (the “Operator”), as per the terms of the “First
Extension Period” as set out in the petroleum agreement (the “Zag
Petroleum Agreement”) dated June 18, 2009 between Office National
des Hydrocarbures et des Mines (“ONHYM”), the Operator and Longreach
Oil and Gas Ventures Limited. Following the joint venture not
completing the minimum work commitment of the First Extension
Period, a twelve month extension to the First Extension Period was
agreed by the joint venture, to May 2016. During the twelve month
extension the Company continued to seek a mutually agreed technical,
commercial and financial proposal to reduce its financial exposure
insofar as possible. The Company has accrued US$1.2 million penalty
costs based on its working interest in the joint venture as the
joint venture has not met the minimum work commitments required by
the licence and the operator has been notified of the same. The
US$0.6 million of restricted cash lodged as a bank guarantee is
available to offset this potential penalty. Subsequent to the year-
end, in March 2017, ONHYM advised the Operator and the Company that
the bank guarantee had been deemed forfeited, and in addition, that
the joint venture should pay the residual penalty ($0.6 million net
to the Company), to ONHYM. The Company has notified ONHYM that a
“force majeure” has occurred pursuant to the Zag Petroleum Agreement
due to financial, commercial and operational challenges on the
licence over a number of years. The Company will seek to work with
ONHYM and the Operator to expedite a mutually agreed resolution,
however reserves the right to preserve its rights, which may include
legal arbitration.
— Previously capitalised costs, which were impaired in 2014, continue
to remain impaired.

/T/

About PetroMaroc

PetroMaroc Corporation plc is an independent oil and gas exploration company.
PetroMaroc holds a substantial share position in Sound Energy plc, and net
profit interests in the Sidi Moktar licence (onshore Morocco), which the
Company considers to be a committed long-term partner who will work to unlock
the hydrocarbon potential of the Essaouira region. PetroMaroc is a public
company and its common shares are listed on the TSX Venture Exchange under the
symbol “PMA”.

Special Note Regarding Forward-Looking Statements

This press release contains forward-looking statements. Such forward-looking
statements relate to future events or the Company’s future performance. All
statements other than statements of historical fact are forward-looking
statements. Forward-looking statements are often, but not always, identified by
the use of words such as “may”, “will”, “should”, “expect”, “plan”,
“anticipate”, “believe”, “estimate”, “predict”, “project”, “potential”,
“targeting”, “intend”, “could”, “might”, “continue” or the negative of these
terms or other similar terms. Forward-looking statements in this press release
include, but are not limited to, statements regarding the strength of the
ongoing relationship between the Company and Sound Energy, including the
ability of the Company to leverage off Sound Energy’s operating capabilities in
Morocco, the degree of success in connection with the proposed drilling of the
Kechula structure to prove the commercial viability of Sidi Moktar and the
value of the net profit interests held by the Company thereon, the ability of
the Company to maintain cost reductions at current levels, the ability of the
Company to continue to successfully negotiate settlement agreements with its
trade creditors in respect to the Sidi Moktar drilling campaign, the value of
Sound Energy shares held by the Company which may impact the ability of the
Company to repay the principal and interest owing under the New Debentures on
maturity, the ability of the Company to negotiate with ONHYM to reduce its
potential exposure in respect of the Zag concession, the completion of
evaluations and processing and interpretation of data, the performance
characteristics of the Company’s interests in oil and gas properties, capital
expenditure programmes, supply and demand for oil, gas and commodities, prices
for oil and gas, drilling plans, and realization of the anticipated benefits of
acquisitions.

Forward-looking statements are only predictions. Forward-looking statements
involve known and unknown risks, uncertainties and other factors that may cause
actual results or events to differ materially from those anticipated in such
forward-looking statements. Some of the risks and other factors which could
cause results to differ materially from those expressed in the forward-looking
statements contained in this press release include, but are not limited to:
unsuccessful test results to be conducted by Sound Energy in respect of the
Sidi Moktar concession, the potential decline in the value of the shares in
Sound Energy held by the Company which may impact upon the ability of the
Company to repay the New Debentures on maturity, the general economic
conditions in Canada, the Kingdom of Morocco and globally; industry conditions,
including fluctuations in the price of oil and gas, governmental regulation of
the oil and gas industry, including environmental regulation; fluctuation in
foreign exchange or interest rates; risks inherent in oil and gas operations;
political risk, including geological, technical, drilling and processing
problems; unanticipated operating events which could cause commencement of
drilling and production to be delayed; the need to obtain consents and
approvals from industry partners, regulatory authorities and other
third-parties; stock market volatility and market valuations; competition for,
among other things, capital, acquisitions of reserves, undeveloped land and
skilled personnel; incorrect assessments of the value of acquisitions or
resource estimates; any future inability to obtain additional funding, when
required, on acceptable terms or at all; credit risk; changes in legislation;
any unanticipated disputes or deficiencies related to title matters; dependence
on management and key personnel; and risks associated with operating in and
being part of a joint venture.

Although the forward-looking statements contained in this press release are
based upon factors and assumptions which management of the Company believes to
be reasonable, the Company cannot assure that actual results will be consistent
with its expectations and assumptions. Undue reliance should not be placed on
the forward-looking statements contained in this news release as there can be
no assurance that the plans, intentions or expectations upon which they are
based will occur. These statements speak only as of the date of this press
release, and the Company does not undertake any obligation to publicly update
or revise any forward-looking statements except as expressly required by
applicable securities laws.

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that
term is defined in policies of the TSX Venture Exchange) accepts responsibility
for the adequacy or accuracy of this release.

This news release does not constitute an offer to sell or a solicitation of an
offer to buy any securities of PetroMaroc in any jurisdiction in which such
offer, solicitation or sale would be unlawful. The securities referred to
herein have not been and will not be registered under the United States
Securities Act of 1933 (the “U.S. Securities Act”) or any state securities laws
and may not be offered or sold within the United States or to U.S. Persons (as
defined in the U.S. Securities Act) unless registered under the U.S. Securities
Act and applicable state securities laws, or an exemption from such
registration is available.

– END RELEASE – 27/04/2017

For further information:
PetroMaroc Corporation plc
Martin Arch
Chief Financial Officer
+44 (0) 20 3137 7756

COMPANY:
FOR: PETROMAROC CORPORATION PLC
TSX VENTURE SYMBOL: PMA

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170427CC0001

Press Release from Marketwired 1-866-736-3779

Suncor Energy reports net earnings of $1.35 billion on higher prices, production

April 26, 2017 by The Canadian Press

CALGARY — Suncor Energy is reporting net earnings of $1.35 billion or 81 cents per share in the first quarter of 2017, compared with $257 million or 17 cents a year earlier, thanks to higher commodity prices and oilsands production.

The company reports operating earnings of $812 million or 49 cents per common share, beating the 31 cents estimated by a consensus of analysts polled by Thomson Reuters.

A year ago, it posted an operating loss of $500 million or 33 cents per share.

Suncor says it had total upstream production of 725,100 barrels of oil equivalent per day in the three months ended March 31, compared with 691,400 boe/d in the year-earlier quarter, driven mainly by its increased ownership interest in Syncrude Canada acquired during 2016.

Oilsands production came to 448,500 barrels per day in the first quarter of 2017.

Suncor cut its expectation for its share of Syncrude production this year by 15,000 barrels per day to between 135,000 and 150,000 bpd because of a fire at Syncrude’s Mildred Lake oilsands upgrader on March 14.

It added 15,000 barrels of oil equivalent to its expectations for non-oilsands production at 110,000-120,000 boe/d to leave its overall guidance unchanged.

“Our commitment to operational excellence remains a top priority and we will continue to seek ways to become more efficient, including development of regional synergies with Syncrude,” says CEO Steve Williams in a statement.

“We were able to partially mitigate the impact of the Syncrude incident by making use of Suncor’s operational flexibility and that’s an indication of the future benefits of integration.”

Suncor says it reached agreement with other Syncrude consortium members during the first quarter to develop regional synergies at Syncrude through integration with Suncor’s oilsands mining works.

Suncor increased its ownership of Syncrude Canada last year from 12 per cent to over 53 per cent by buying Canadian Oil Sands Ltd., which had a 37 per cent stake, and adding Murphy Oil’s five per cent interest.

The Canadian Press

Divestco Reports 2016 Q4 and Annual Results

April 26, 2017 by The Canadian Press

FOR: DIVESTCO INC.
TSX VENTURE Symbol: DVT

Date issue: April 27, 2017
Time in: 12:45 AM e

Attention:

CALGARY, AB –(Marketwired – April 27, 2017) – (TSX VENTURE: DVT) – Divestco
Inc. (“Divestco” or the “Company”), an exploration services company dedicated
to providing a comprehensive and integrated portfolio of data, software and
services to the oil and gas industry worldwide, today announced its financial
and operating results for the three months and year ended December 31, 2016.

Financial Highlights

Overall Performance and Operational Results

Financial Results (Thousands, Except Per Share Amounts)

/T/

—————————————————————————-

Three months ended December 31 ————R $ % 2016 2015 Change Change ————R
Revenue $ 7,679 $ 2,863 $4,816 Operating
Expenses
(1) 2,501 3,256
Other
Loss
(Income) 18 (21) 39 N/A ————R EBITDA
(2) 5,160 (372) 5,532
Finance
Costs 236 334
Depreciation
and
Amortiza-
tion 1,627 1,438 189 ————R
Net
Income
(Loss) $ 3,297 $(3,366) $6,663 Per
Share
–
Basic
and
Diluted 0.05 (0.05) 0.10 ————R
Funds
from
(used
in)
Opera-
tions $ 4,136 $ (382) $4,518 Per
Share
–
Basic
and
Diluted 0.06 (0.01) 0.07 ————R
Class A
Shares
Outstand-
ing 66,884 67,208 Year ended December 31
12;————————————————————-
$ %
2016 2015 Change Change
12;————————————————————-
168% $15,966 $18,314 $(2,348) -13%
(755) -23% 10,141 15,754 (5,613) -36%
80 (5,517) 5,597 N/A
12;————————————————————-
N/A 5,745 8,077 (2,332) -29%
(98) -29% 1,305 1,181 124 10%
13% 6,377 11,403 (5,026) -44%
12;————————————————————-
N/A $(1,937) $(5,729) $ 3,792 N/A
N/A (0.03) (0.09) 0.06 N/A
12;————————————————————-
N/A $ 4,703 $ 2,648 $ 2,055 78%
N/A 0.07 0.04 0.03 75%
12;————————————————————-
N/A N/A 66,884 67,208 N/A N/A

Weighted
Average
Shares
Outstanding
Basic

and
Diluted 67,150 67,126 N/A N/A 67,217 67,117 N/A N/A
—————————————————————————-

/T/

(1) Includes salaries & benefits, general & administrative expenses and
share-based payments but excludes depreciation and amortization and other
losses (income)
(2) See the “Non GAAP Measures” section of the Company’s Management Discussion
and Analysis filed on the Company’s website and on SEDAR

Q4 2016 vs. Q4 2015

Divestco generated revenue of $7.7 million in Q4 2016 compared to $2.9 million
in Q4 2015, an increase of $4.8 million (168%) which was mainly due to the
Company’s Seismic Data segment with the commencement of a new seismic survey
and strong data library sales. This was partially offset by lower Services and
Software & Data revenue as result of reduced capital spending by clients
caused by low commodity prices. Revenue in the Seismic Data segment ($6.3
million) increased by $5.7 million (891%). Revenue in the Software & Data
segment ($0.8 million) decreased by $0.3 million (25%) and revenue in the
Services segment ($0.6 million) decreased by $0.5 million (47%).

Operating expenses decreased by $0.8 million (23%) to $2.5 million in Q4 2016
from $3.3 million in Q4 2015. Salaries declined by $0.7 million (38%) due to
reduced staffing levels and the austerity measures put in place in response to
the economic conditions in 2015 and 2016. G&A expenses declined by $27,000
(2%) due to a decrease in discretionary expenses, stock-based compensation, as
well as software licences and contractor fees offset by an increase in bad
debts.

Finance costs decreased by $98,000 (29%) to $236,000 in Q4 2016 from $334,000
in Q4 2015.

Depreciation and amortization was $1.6 million in Q4 2016 compared to $1.4
million in Q4 2015, an increase of $0.2 million (13%).

There was no impairment charge in Q4 2016 compared to $1.2 million in Q4 2015.

Year Ended December 31, 2016 vs. Year Ended December 31, 2015

Divestco generated revenue of $16 million during 2016 compared to $18.3
million in 2015, a decrease of $2.3 million (13%). Lower Services and Software
& Data revenue was partially offset by higher Seismic Data revenue. Revenue in
the Seismic Data segment ($9.3 million) increased by $3.1 million (51%) due to
higher data library sales partially offset by slight lower seismic
participation revenue; there were three surveys completed in Q1 2015 and a new
survey commenced in Q4 2016. Revenue in the Services segment ($2.6 million)
decreased by $4.2 million (62%) mainly due to a reduction in activity levels
caused by low commodity. Revenue in the Software & Data segment ($4.1 million)
decreased by $1.3 million (24%) mainly due to the sale of the land software
assets in Q1 2015 and reduced industry activity. Seismic brokerage revenue
decreased due to lower activity levels.

Operating expenses decreased by $5.7 million (36%) to $10.1 million in 2016
from $15.8 million in 2015. Salaries declined by $3.8 million (41%) due to
reduced staffing levels and the austerity measures put in place in response to
current economic conditions. G&A expenses declined by $1.9 million (27%) due
to a decrease in discretionary expenses as well as software licences and
contractor fees.

Finance costs increased by $0.1 million (10%) to $1.3 million in 2016 from
$1.2 million in 2015 mainly related to repayment of a $4.5 million bridge loan
in March 2015. The Company then secured a new bridge loan in September 2015.
Thus, debt levels were higher during 2016 compared to 2015.

Depreciation and amortization decreased by $5 million (44%) to $6.4 million
from $11.4 million in 2015 mainly due to the addition of new seismic data in
2015. No new surveys were completed in 2016; however, a survey commenced in Q4
2016 and was completed in Q1 2017.

There was no impairment charge in 2016 compared to $1.2 million in 2015.

Financial Position (1)

As at December 31, 2016, Divestco had a working capital deficiency of $3.9
million (December 31, 2015: $2.1 million deficiency), excluding deferred
revenue of $1.7 million (December 31, 2015: $1.3 million). The increase in the
working capital deficit from the end of 2015 was due to the reclassification
of the Company’s bridge loan to current at December 31, 2016. The bridge loan
was repaid in March 2017 with the proceeds of a new term loan with the balance
being used for working capital purposes.

(1) See the “Non GAAP Measures” section of the Company’s Management Discussion
and Analysis filed on the Company’s website and on SEDAR

Operations Update and Outlook

There has been an improvement in West Texas Intermediate oil prices from a low
of US$27/barrel in February 2016 to US$50/barrel currently and rig utilization
has improved from 12.5% in July 2016 to 23% in March 2017. However, commodity
prices and rig utilization remain significantly lower than 2014 levels which
forced most North American oil and gas producers to keep their capital
spending to historically low levels. Access to capital also remains
challenging for the industry. Due to significantly lower activity levels,
Divestco implemented several salary austerity measures in 2015 and 2016. These
are expected to remain in place for the remainder of 2017 or until a change in
activity levels is realized.

Mr. Stephen Popadynetz, CEO and President commented: “We spent two years
focusing on cost control resulting in Divestco lowering its operating expenses
by over 50% from 2014 to 2016. Towards the latter part of 2016, we began to
finally see an increase in activity levels which resulted in a very strong
fourth quarter for Divestco. This allowed us to achieve positive funds from
operations of $4.7 million for 2016, an increase of $2.1 million (78%) from
2015. In addition, we are pleased to report that for the first time in two
years, we returned to acquiring new seismic in Q4 2016 and successfully
completed our first survey in Q1 2017. The increased activity levels
experienced in the last quarter of 2016 have continued and has led to a
general renewed optimism that we haven’t seen in over two years. Many
producers have already announced increased capital spending for 2017, capital
markets are again starting to finance many smaller oil and gas producers and
the glut of distressed assets is being resolved through acquisition. These
factors point to new opportunities for Divestco to start growing again. As
well, during this downturn, Divestco focused much of its strategy on
international markets and we have been receiving bids for a significant number
of international opportunities. These strategies all led to Divestco
negotiating a new bank financing and retiring our $3.2 million bridge loan in
March 2017. With improved working capital and stronger sales opportunities, we
look forward to delivering significantly improved results and rewarding our
patient shareholders.”

About the Company

Divestco is an exploration services company that provides a comprehensive and
integrated portfolio of data, software, and services to the oil and gas
industry. Through continued commitment to align and bundle products and
services to generate value for customers, Divestco is creating an unparalleled
set of integrated solutions and unique benefits for the marketplace.
Divestco’s breadth of data, software and services offers customers the ability
to access and analyze the information required to make business decisions and
to optimize their success in the upstream oil and gas industry. Divestco is
headquartered in Calgary, Alberta, Canada and trades on the TSX Venture
Exchange under the symbol “DVT”.

Additional information on the Company is available on its website at
Divestco.com and on SEDAR at sedar.com.

Neither TSX Venture Exchange nor its Regulation Services Provider (as that
term is defined in the policies of the TSX Venture Exchange) accepts
responsibility for the adequacy or accuracy of this news release.

This press release contains forward-looking information related to the
Company’s capital expenditures, projected growth, view and outlook with
respect to future oil and gas prices and market conditions, and demand for its
products and services. Statements that contain words such as “could’,
“should”, “can”, “anticipate”, “expect”, “believe”, “will”, “may” and similar
expressions and statements relating to matters that are not historical facts
constitute “forward-looking information” within the meaning applicable by
Canadian securities legislation. Although management of the Company believes
that the expectations reflected in such forward-looking information are
reasonable, there can be no assurance that such expectations will prove to
have been correct because, should one or more of the risks materialize, or
should the assumptions underlying forward-looking statements or
forward-looking information prove incorrect, actual results may vary
materially from those described in this press release as intended, planned,
anticipated, believed, estimated or expected. Readers should not place undue
reliance on forward-looking statements or forward-looking information. All of
the forward-looking statements and forward-looking information of the Company
contained in this press release are expressly qualified, in their entirety, by
this cautionary statement. Except where required by law, the Company does not
assume any obligation to update these forward-looking statements or
forward-looking information if conditions or opinions should change.

In particular, this press release contains forward-looking statements
pertaining to the following: Company’s ability to keep debt and liquidity at
acceptable levels, improve/maintain its working capital

position and maintain profitability in the current economy; availability of
external and internal funding for future operations; relative future
competitive position of the Company; nature and timing of growth; oil and
natural gas production levels; planned capital expenditure programs; supply
and demand for oil and natural gas; future demand for products/services;
commodity prices; impact of Canadian federal and provincial governmental
regulation on the Company; expected levels of operating costs, finance costs
and other costs and expenses; future ability to execute acquisitions and
dispositions of assets or businesses; expectations regarding the Company’s
ability to raise capital and to add to seismic data through new seismic shoots
and acquisition of existing seismic data; treatment under tax laws; and new
accounting pronouncements.

These forward-looking statements are based upon assumptions including: future
prices for crude oil and natural gas; future interest rates and future
availability of debt and equity financing will be at levels and costs that
allow the Company to manage, operate and finance its business and develop its
software products and various oil and gas datasets including its seismic data
library, and meet its future obligations; the regulatory framework in respect
of royalties, taxes and environmental matters applicable to the Company and
its customers will not become so onerous on both the Company and its customers
as to preclude the Company and its customers from viably managing, operating
and financing its business and the development of its software and data; and
that the Company will continue to be able to identify, attract and employ
qualified staff and obtain the outside expertise as well as specialized and
other equipment it requires to manage, operate and finance its business and
develop its properties.

These forward-looking statements are subject to numerous risks and
uncertainties, certain of which are beyond the Company’s control, including:
general economic, market and business conditions; volatility in market prices
for crude oil and natural gas; ability of Divestco’s clients to explore for,
develop and produce oil and gas; availability of financing and capital;
fluctuations in interest rates; demand for the Company’s product and services;
weather and climate conditions; competitive actions by other companies;
availability of skilled labour; failure to obtain regulatory approvals in a
timely manner; adverse conditions in the debt and equity markets; and
government actions including changes in environment and other regulation.

– END RELEASE – 27/04/2017

For further information:

For more information please contact:
Divestco Inc.
(www.divestco.com)

Mr. Stephen Popadynetz
CEO and President
Tel 587-952-8152

Mr. Danny Chiarastella
CFO
Tel 587-952-8027

COMPANY:
FOR: DIVESTCO INC.
TSX VENTURE Symbol: DVT

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170427CC002

Press Release from Marketwired 1-866-736-3779

Xtreme Drilling Corp. announces Election of Directors

April 26, 2017 by The Canadian Press

FOR: XTREME DRILLING CORP.TSX SYMBOL: XDCDate issue: April 26, 2017Time in: 11:57 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 26, 2017) – Xtreme Drilling Corp.
(“Xtreme”) (TSX:XDC) is pleased to announce that the nominees listed in the
infor…

Cenovus CEO defends much-criticized $17.7B blockbuster ConocoPhillips deal

April 26, 2017 by The Canadian Press

CALGARY — A $17.7-billion megadeal to buy most of the Canadian assets of ConocoPhillips will make Cenovus Energy Inc. (TSX:CVE) a “better and stronger company,” CEO Brian Ferguson said Wednesday in a staunch response to the deal’s critics.

Calgary-based Cenovus’s share price has fallen more than 20 per cent since the acquisition was announced March 29 and an investor, Toronto-based Coerente Capital Management, has asked the Ontario Securities Commission to halt the deal.

Coerente wants to put the decision to a shareholder vote because it dilutes the existing shareholders’ float by more than 25 per cent.

But Ferguson said Wednesday morning on a conference call with analysts and later at the company’s annual meeting that the price and structure of the deal are appropriate.

“I believe it is the right transaction for us and that we have structured the transaction in the right way to maintain our financial strength,” he said on the call.

“I don’t know specifically what’s been asked of the Ontario Securities Commission but I would just emphasize that the transaction was undertaken in full compliance with all securities regulations.”

At the company’s annual meeting on Wednesday afternoon in Calgary, shareholders voted more than 87 per cent in favour of re-electing the board of directors, a result Ferguson interpreted as a vote of confidence.

Of three shareholders who spoke, only one said that Cenovus should have held a shareholder vote on the ConocoPhillips deal.

“If you guys are so confident about this deal why don’t shareholders have the opportunity to vote on this matter?” said the man. He later told reporters he owns 1,500 shares but wouldn’t give his name.

Cenovus chairman Michael Grandin responded that the “once in a lifetime” opportunity could have been lost if word of the deal had leaked out before financing and terms were finalized.

Cenovus is buying Houston-based ConocoPhillips’s 50 per cent interest in the FCCL Partnership, an oilsands venture between the two companies in northern Alberta, as well as most of its Deep Basin conventional assets in Alberta and British Columbia.

The price includes $14.1 billion in cash and 208 million Cenovus common shares. Part of the cash has been raised by selling a further 188 million shares for $3 billion.

It also plans to raise at least $3.6 billion from dispositions by the end of the year and may sell other non-core assets.

Ferguson said Cenovus is finding plenty of buyer interest in its legacy Alberta conventional assets at Pelican Lake and Suffield.

The ConocoPhillips deal is expected to close by June 30.

Cenovus reported oilsands production in northern Alberta rose 32 per cent in the first quarter ended March 31 from the same time last year as volumes ramped up from two new oilsands expansion projects.

Higher prices helped to fuel a nearly $1.7-billion rise in revenue from a year earlier to $3.87 billion — Cenovus’s average crude oil sales price was C$41.41 per barrel in the first quarter, up from $15.97 in the same period of 2016 when benchmark oil prices touched 13-year lows.

It reported a net profit of $211 million or 25 cents per share versus a net loss of $118 million or 14 cents in the year-earlier quarter.

Its operating loss was five cents per share, while analysts on average were estimating a loss of eight cents per share, according to Thomson Reuters.

Follow @HealingSlowly on Twitter.

Dan Healing, The Canadian Press

How to Find Top Talent Using Indeed Resume – FREE Webinar, May 10, 2017 Register Details HERE

June 28, 2017April 26, 2017 by EnergyNow Media

Wednesday, May 10th, 2017 at 2:00pm EDT / 11:00am PDT Finding the right candidate is hard work. The right mix of experience, education and skills can sometimes feel like finding a needle in a haystack. We’re here to help. Indeed Resume gives you instant access to over 80 million resumes worldwide, with over 3.5 million … Read more

Nova Scotia companies vying for contracts as Sable gas field nears end of life

April 26, 2017 by The Canadian Press

HALIFAX — The delicate task of dismantling the Sable Offshore Energy Project is set to begin next year, and local suppliers are lining up for a piece of the lucrative work.

More than 100 companies attended a suppliers forum in a downtown Halifax ballroom Wednesday to learn about the retirement of the natural gas field off the coast of Nova Scotia, which started producing in late 1999 and would pay nearly $2 billion in royalties to the province.

Decommissioning manager Friedrich Krispin told the business crowd it’s essential for the offshore facility to “finish strong.”

“Our activities have been conducted in what is deemed to be an environmentally responsible manner,” he said. “We will leave behind a strong record … but this is only the case if we finish strong.”

The Sable project, a consortium of five companies majority-owned by ExxonMobil Canada, is made up of seven offshore platforms, 22 wells and 340 kilometres of subsea pipeline.

Krispin said the pipelines will be flushed to remove hydrocarbons, filled with water and capped.

He said leaving the pipeline on the ocean floor is “current industry practice.”

“This method has demonstrated it will cause less environmental damage and disruption to established sea life,” Krispin said. “However, there might be cases where portions of these pipelines could present a hazard and will have to be either mitigated or removed.”

Mark Butler, policy director of the Halifax-based Ecology Action Centre, said oil and gas giants should clean up after themselves.

“It’s the basic principle that if you’re going to extract oil and gas, you need to … leave it as pristine as possible,” he said.

Michel Samson, Nova Scotia’s energy minister, referred questions about the shut down and cleanup to the Canada-Nova Scotia Offshore Petroleum Board, saying it was up to the independent regulator to decide what to do about the pipelines.

Board spokeswoman Stacy O’Rourke said leaving the pipeline in place was approved before the project started.

The Sable facility includes five natural gas fields spread over 200 square kilometres in the North Atlantic Ocean near Sable Island, which is now a national park reserve. The small, crescent-shaped island about 300 kilometres southeast of Halifax is known for its rugged landscape and pony-sized wild horses.

Four companies have already been awarded major contracts for the decommissioning work: Halliburton Group Canada, Noble Drilling Services, ABM Offshore and Heerema Marine Contractors.

In matchmaking sessions held by the Maritimes Energy Association behind closed doors, companies had 10-minute, one-on-one meetings with the major contractors.

Calls for bids on a wide range of work are expected in the coming months.

Work to shut down the facility is slated to start early next year and run for two years before all 22 wells are plugged and abandoned.

Energy Department spokeswoman Barbara MacLean said the companies that own the project will pay the decommissioning costs.

“These costs are factored into the calculation of how much royalties these companies owe the province,” she said in an email. “Decommissioning costs are confidential, and not something we are able to share.”

Brett Bundale, The Canadian Press

Questfire Energy Corp. Announces 2016 Financial Results and Files Its Annual Information Form

April 26, 2017 by The Canadian Press

FOR: QUESTFIRE ENERGY CORP.
TSX VENTURE SYMBOL: Q.A

Date issue: April 26, 2017
Time in: 8:29 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 26, 2017) –

NOT FOR DISSEMINATION IN THE UNITED STATES OR TO U.S. PERSONS

Questfire Energy Corp. (the “Corporation” or “Questfire”) (TSX VENTURE:Q.A) is
pleased to announce that it has filed on SEDAR its audited financial
statements, related management’s discussion and analysis (“MD&A”) and Annual
Information Form (AIF) for the year ended December 31, 2016. Included in the
AIF are the Corporation’s reserves data and other oil and gas information as of
December 31, 2016 as prepared by GLJ Petroleum Consultants Ltd. (GLJ), the
Corporation’s independent reserves evaluator. The evaluation was prepared in
accordance with National Instrument 51-101 – Standards of Disclosure for Oil
and Gas Activities.

Financial and Operating Highlights

/T/

Three months ended December
31, Year ended December 31,
2016 2015 2016 2015
—————————————————————————-
Financial
Oil and natural gas
sales $ 10,445,951 $ 9,405,900 $ 32,180,438 $ 40,717,011
Funds flow from
operations (1) 2,550,831 2,627,473 4,833,132 11,543,473
Per share, basic 0.13 0.15 0.27 0.67
Per share, diluted 0.11 0.11 0.21 0.48
Income (loss) 2,752,322 (1,152,161) (7,528,123) (10,386,781)
Per share, basic 0.14 (0.07) (0.42) (0.60)
Per share, diluted 0.12 (0.07) (0.42) (0.60)
Capital expenditures 230,858 82,743 650,489 4,955,048
Proceeds from
property
dispositions $ 8,352,653 $ – 10,610,040 –
Working capital
deficit (end of
period) (2) 41,325,801 9,653,400
Long-term contract
obligation (end of
period) (3) 13,760,534 14,155,697
Long-term bank debt
(end of period) – 41,406,473
Shareholders’ equity
(end of period) $ 12,715,156 $ 14,251,344
Shares outstanding
(end of period)
Class A 22,822,401 17,318,001
Class B – 550,440
Options outstanding
(end of period) 3,133,500 3,566,000
Weighted-average
basic shares
outstanding 19,232,575 17,318,001 17,799,260 17,318,001
Weighted-average
diluted shares
outstanding 23,473,125 17,318,001 17,799,260 17,318,001
Class A share
trading price
High $ 0.59 $ 1.44 $ 0.74 $ 1.95
Low 0.24 0.30 0.24 0.30
Close $ 0.34 $ 0.59 $ 0.34 $ 0.59
Operations(4)
Production
Natural gas
(Mcf/d) 20,746 23,245 21,008 21,741
Natural gas
liquids (NGL)
(bbls/d) 695 674 706 647
Crude oil (bbls/d) 368 512 424 606
Total (boe/d) 4,521 5,060 4,631 4,877
Benchmark prices
Natural gas
AECO (Cdn$/GJ) $ 2.94 $ 2.34 $ 2.05 $ 2.55
Crude oil
WTI (US$/bbl) 49.29 42.18 43.32 48.80
Canadian Light
(Cdn$/bbl) 60.76 52.55 52.79 57.45
Average realized
prices (5)
Natural gas (per
Mcf) 3.27 2.57 2.30 2.78
NGL (per bbl) 34.97 31.74 29.16 34.24
Crude oil (per
bbl) 58.30 41.02 44.88 47.89
Operating netback
(per boe)(6) 11.28 6.89 6.45 8.48
Funds flow netback
(per boe) (6) $ 6.13 $ 5.64 $ 2.85 $ 6.49
(1 For a description of Funds flow from operations, refer to the commentary
) in the MD&A under Funds flow from operations under Critical Accounting
Judgments, Estimates and Policies.
(2) Working capital deficit includes risk management contract and
convertible Class B share liabilities of $2,957,743 and $Nil,
respectively (December 31, 2015 – risk management contract assets of
$Nil and convertible Class B share liability of $5,086,857). Excluding
this, the working capital deficit would be $38,368,058 (December 31,
2015 – $4,566,543).
(3) Long-term contract obligation excludes current portion of $395,163
(December 31, 2015 – $344,448), which is included in working capital
deficit.
(4) For a description of the boe conversion ratio, see “Reader Advisory”.
(5) Before hedging.
(6) For a description of Operating netback and Funds flow netback, refer to
the commentary in the MD&A under Non-GAAP measures.

/T/

2016 Corporate Highlights

/T/

— Achieved average production of 4,631 boe per day for the year and 4,521

boe per day for the fourth quarter, 76 percent natural gas. The average
production for 2016 is within 5 percent of the 4,877 boe per day
produced in 2015 despite having no drilling activity in 2016,
underscoring the benefits of the Corporation’s low-decline production
base.
— Generated a sharply improved fourth quarter operating netback of $11.28
per boe compared to $6.89 per boe in the fourth quarter of 2015 and
$7.84 per boe in the third quarter of 2016.
— Achieved funds flow from operations of $4.8 million ($0.27 per basic
share) on sales of $32.2 million during 2016. Although full-year funds
flow was down significantly from 2015, fourth-quarter 2016 funds flow
from operations of $2.6 million was essentially unchanged from the
fourth quarter of 2015.
— Minimized capital spending with no new drilling, resulting in total
capital expenditures of $650,489.
— Incurred operating costs of $10.98 per boe in the fourth quarter and
$10.46 per boe in the full year. Annual operating costs per unit of
production declined by 11 percent from 2015.
— Incurred general and administrative (G&A) costs of $4.4 million for the
year, representing a 15 percent reduction from 2015.
— Revised the maturity of the Corporation’s bank facility to May 31, 2017
and amended the terms to include a revised $28 million operating and
syndicated facility plus an $8.1 million supplemental facility.

/T/

President’s Message

Two-thousand sixteen marked the third year of a significant downturn for the
oil and natural gas industry, largely driven by weak commodity prices. Rather
than experiencing a recovery in oil and gas prices as widely expected, the
first half of 2016 saw prices for both oil and gas continue to drop to 20-year
lows. This hit Questfire particularly hard as we had virtually no commodity
price hedges for the first half of 2016. Along with reduced commodity prices
came downward revisions to our senior bank borrowing base.

In response to these significant challenges our strategy, as always, was to
work hard to make the best of a tough situation. Over the year we sold
approximately 120 boe per day of non-core production, generating proceeds of
approximately $10.6 million, all of which was applied to reduce debt. We
minimized capital spending which resulted in no new drilling and only $650,489
of capital spending on mandatory maintenance and miscellaneous projects. We
also continued to focus on cost reductions, achieving a 15 percent reduction in
gross G&A costs and an 11 percent reduction in unit operating costs over 2015.
The Questfire management and field operations team worked hard to reduce all
downtime and maintain maximum production while minimizing spending. Along with
the low-decline nature of our production base, this held the year-over-year
decline in average annual production to just 5 percent. We are very satisfied
with this result given no drilling, 120 boe per day of asset sales and very low
capital spending.

The second half of 2016 saw slow and steady improvement in commodity prices
and, as a result, essentially all $4.8 million of our funds flow from
operations for the year was generated in the second half of 2016. In December,
our bank facility was extended to May 31, 2017 with a $28 million conforming
and an $8.1 million supplemental facility. With the fourth quarter’s sharply
improved operating netback, the continued nearly flat production, the higher
realized pricing for all commodities and the essentially flat funds flow from
operations from the fourth quarter of 2015, we are optimistic that Questfire’s
overall position will continue to improve.

The outlook for commodity prices is positive for 2017 and beyond. The
improvement in pricing is happening at a slow pace compared to past recoveries,
but the fundamentals are in place for further gains. Questfire’s goals for 2017
include continued reduction in overall debt and achieving an extension of
banking facilities beyond May 31, 2017. With continued debt reduction and
improvement in commodity prices, we expect to return to drilling and growth in
the second half of 2017.

Questfire Energy Corp. is an Alberta-based company formed to participate in oil
and gas exploration, development and acquisitions focusing in the W4 and W5
regions of Alberta. The Corporation’s shares trade on the TSX Venture exchange
under the symbol Q.A. The Corporation currently has 22,822,401 Class A shares
outstanding.

To view a full copy of the Corporation’s financial results for the year ended
December 31, 2016, including the Corporation’s audited financial statements and
accompanying MD&A, please refer to the SEDAR website at www.sedar.com or
contact the Corporation at Questfire Energy Corp., 1100, 350 – 7th Ave S.W.,
Calgary, Alberta, T2P 3N9.

Reader Advisory

Petroleum and natural gas volumes are stated as a “barrel of oil equivalent”
(boe), derived by converting gas to an oil equivalency in the ratio of 6,000
cubic feet of gas to one barrel of oil. Boe may be misleading, particularly if
used in isolation. A boe conversion ratio of 6,000 cubic feet of gas to one
barrel of oil is based on an energy equivalency conversion method primarily
applicable at the burner tip and does not represent a value equivalency at the
wellhead which under current commodity price conditions is approximately 15-30
Mcf to 1 bbl. Readers are cautioned that boe figures may be misleading,
particularly if used in isolation.

This news release contains certain forward-looking statements, including
management’s assessment of future plans and operations, and capital
expenditures and the timing thereof, that involve substantial known and unknown
risks, uncertainties, and assumptions certain of which are beyond Questfire’s
control. Such risks, uncertainties, and assumptions include, without
limitation, risks associated with oil and gas exploration, development,
exploitation, production, marketing and transportation, loss of markets,
volatility of commodity prices, currency fluctuations, imprecision of reserve
estimates, environmental risks, competition from other producers, inability to
retain drilling rigs and other services, delays resulting from or inability to
obtain required regulatory approvals and ability to access sufficient capital
from internal and external sources, the impact of general economic conditions
in Canada, the United States and overseas, industry conditions, changes in laws
and regulations (including the adoption of new environmental laws and
regulations) and changes in how they are interpreted and enforced, increased
competition, the lack of availability of qualified personnel or management,
fluctuations in foreign exchange or interest rates, stock market volatility and
market valuations of companies with respect to announced transactions and the
final valuations thereof, and obtaining required approvals of regulatory
authorities. Questfire’s actual results, performance or achievements could
differ materially from those expressed in, or implied by, these forward-looking
statements and, accordingly, no assurances can be given that any of the events
anticipated by the forward-looking statements will transpire or occur, or if
any of them do so, what benefits, including the amount of proceeds, that
Questfire will derive therefrom. Readers are cautioned that the foregoing list
of factors is not exhaustive. All subsequent forward-looking statements,
whether written or oral, attributable to Questfire or persons acting on its
behalf are expressly qualified in their entirety by these cautionary
statements. Furthermore, the forward-looking statements contained in this news
release are made as at the date of this news release and Questfire does not
undertake any obligation to update publicly or to revise any of the included
forward-looking statements, whether as a result of new information, future
events or otherwise, except as may be required by applicable securities laws.

To request a free copy of Questfire’s financial report or if you would like to
be put on Questfire’s mailing list please contact Ronald Williams, Vice
President, Finance and CFO at rwilliams@questfire.ca.

– END RELEASE – 26/04/2017

For further information:
Questfire Energy Corp.
Mr. Richard Dahl
President and CEO
(403) 263-6691
(403) 263-6683 (FAX)
OR
Questfire Energy Corp.
Mr. Ronald Williams
Vice President, Finance and CFO
(403) 263-6658
(403) 263-6683 (FAX)

COMPANY:
FOR: QUESTFIRE ENERGY CORP.
TSX VENTURE SYMBOL: Q.A

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170426CC0114

Press Release from Marketwired 1-866-736-3779

Cenovus reports voting results of election of Directors

April 26, 2017 by The Canadian Press

FOR: CENOVUS ENERGY INC.
TSX Symbol: CVE
NYSE Symbol: CVE

Date issue: April 26, 2017
Time in: 7:48 PM e

Attention:

CALGARY, AB –(Marketwired – April 26, 2017) – Cenovus Energy Inc. (TSX: CVE)
(NYSE: CVE) announced that at its annual meeting of shareholders held on April
26, 2017 each of the 11 nominees proposed as Directors and listed in its
Management Information Circular dated March 3, 2017 were elected as Directors.
The detailed results of the vote are set out below.

/T/

—————————————————————————-
Nominee Votes for Votes withheld
—————————————————————————-
Number Percent Number Percent
—————————————————————————-
Susan F. Dabarno 538,584,625 87.83 74,626,583 12.17
—————————————————————————-
Patrick D. Daniel 537,895,307 87.72 75,316,195 12.28
—————————————————————————-
Ian W. Delaney 536,731,302 87.53 76,478,235 12.47
—————————————————————————-
Brian C. Ferguson 536,650,354 87.51 76,560,854 12.49
—————————————————————————-
Steven F. Leer 536,895,053 87.55 76,316,155 12.45
—————————————————————————-
Richard J. Marcogliese 538,133,532 87.76 75,076,004 12.24
—————————————————————————-
Claude Mongeau 538,594,552 87.83 74,616,656 12.17
—————————————————————————-
Charles M. Rampacek 534,832,174 87.22 78,379,033 12.78
—————————————————————————-
Colin Taylor 538,053,072 87.74 75,156,758 12.26
—————————————————————————-
Wayne G. Thomson 536,784,027 87.54 76,427,181 12.46
—————————————————————————-
Rhonda I. Zygocki 539,278,454 87.94 73,933,081 12.06
—————————————————————————-

/T/

Cenovus welcomes Susan F. Dabarno as a new member of its Board of Directors.
Ms. Dabarno is a director of Manulife Financial Corporation and has extensive
wealth management and financial expertise. Ms. Dabarno spent seven years with
Richardson Partners Financial Limited, an independent wealth management
services firm, serving as President and Chief Executive Officer and then as
Executive Chair during her tenure. Prior to joining Richardson Partners
Financial Limited, Ms. Dabarno was President and Chief Operating Officer at
Merrill Lynch Canada Inc.

Cenovus would like to extend its sincere thanks and best wishes to Michael A.
Grandin and Valerie A. A. Nielsen, who have retired from the Board of
Directors. Mr. Grandin served as Chair of the Board and Ms. Nielsen as a
Director since Cenovus’s inception in 2009.

Cenovus Energy Inc.

Cenovus Energy Inc. is a Canadian integrated oil company. It is committed to
applying fresh, progressive thinking to safely and responsibly unlock energy
resources the world needs. Operations include oil sands projects in northern
Alberta, which use specialized methods to drill and pump the oil to the
surface, and established natural gas and oil production in Alberta and
Saskatchewan. The company also has 50% ownership in two U.S. refineries.
Cenovus shares trade under the symbol CVE, and are listed on the Toronto and
New York stock exchanges. For more information, visit cenovus.com.

Find Cenovus on Facebook, Twitter, LinkedIn, YouTube and Instagram.

– END RELEASE – 26/04/2017

For further information:

CENOVUS CONTACTS:

Investor Relations
Kam Sandhar
Vice-President
Investor Relations & Corporate Development
403-766-5883

Media
Brett Harris
Manager, External Communications
403-766-3420

Media Relations general line
403-766-7751

COMPANY:
FOR: CENOVUS ENERGY INC.
TSX Symbol: CVE
NYSE Symbol: CVE

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170426CC026

Press Release from Marketwired 1-866-736-3779

Suncor Energy announces increased return to shareholders and early repayment of US $1.25 billion bond

April 26, 2017 by The Canadian Press

FOR: SUNCOR ENERGY INC.TSX SYMBOL: SUNYSE SYMBOL: SUDate issue: April 26, 2017Time in: 7:00 PM eAttention:
All financial figures are in Canadian dollars, unless otherwise noted
CALGARY, ALBERTA–(Marketwired – April 26, 2017) – Suncor today announced …

Pulse Seismic Inc. Reports Q1 2017 Results

April 26, 2017 by The Canadian Press

FOR: PULSE SEISMIC INC.
TSX SYMBOL: PSD
OTCQX SYMBOL: PLSDF

Date issue: April 26, 2017
Time in: 7:00 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 26, 2017) – Pulse Seismic Inc.
(TSX:PSD)(OTCQX:PLSDF) (“Pulse” or “the Company”) is pleased to report its
financial and operating results for the three months ended March 31, 2017. The
unaudited condensed consolidated interim financial statements, accompanying
notes and MD&A are being filed on SEDAR (www.sedar.com) and will be available
on Pulse’s website at www.pulseseismic.com.

HIGHLIGHTS FOR THE THREE MONTHS ENDED MARCH 31, 2017

/T/

— Total revenue, comprised exclusively of data library sales, for the

three months ended March 31, 2017 increased by 54 percent to $2.7
million from $1.8 million for the three months ended March 31, 2016;

— The net loss of $2.5 million ($0.04 loss per share basic and diluted)

was 29 percent less than the net loss of $3.5 million ($0.06 loss per
share basic and diluted) for the same period in 2016;

— Cash EBITDA(a) increased to $1.3 million ($0.02 per share basic and

diluted) from $266,000 ($0.00 per share basic and diluted) for the
comparable period of 2016;

— Shareholder free cash flow(a) was also $1.3 million ($0.02 per share

basic and diluted), up from $225,000 ($0.00 per share basic and diluted)
for the comparable period in 2016;

— In the three-month period ended March 31, 2017 Pulse purchased and

cancelled, through its normal course issuer bid, a total of 583,500
common shares at a total cost of approximately $1.4 million (average
cost of $2.41 per common share including commissions); and

— At March 31, 2017 Pulse was debt-free and had cash of $7.6 million. The

$30.0 million revolving credit facility is undrawn and fully available
to the Company.

SELECTED FINANCIAL AND OPERATING INFORMATION

Three months ended March 31, Year ended
(thousands of dollars except
per share data, 2017 2016 December 31,
number of shares and kilometres
of seismic data) (unaudited) 2016
—————————————————————————-
Revenue
Data library sales 2,719 1,771 14,339

Amortization of seismic data
library 4,635 4,909 18,973
Net loss (2,502) (3,494) (7,490)
Per share basic and diluted (0.04) (0.06) (0.13)
Cash provided by operating
activities 3,298 3,506 9,471
Per share basic and diluted 0.06 0.06 0.17
Cash EBITDA (a) 1,330 266 9,119
Per share basic and diluted
(a) 0.02 0.00 0.16
Shareholder free cash flow (a) 1,254 225 9,029
Per share basic and diluted
(a) 0.02 0.00 0.16
Capital expenditures
Seismic data purchases,
digitization and related
costs 65 2,150 2,444
Property and equipment 27 6 6
—————————————————————————-
Total capital expenditures 92 2,156 2,450
Weighted average shares
outstanding
basic and diluted 55,743,767 56,043,039 56,105,593
Shares outstanding at period-
end 55,337,560 56,208,332 55,921,060
—————————————————————————-
Seismic library
2D in kilometres 447,000 447,000 447,000
3D in square kilometres 28,647 28,613 28,647

FINANCIAL POSITION AND RATIO

March 31, March 31, December 31,
(thousands of dollars except
ratio) 2017 2016 2016
—————————————————————————-
Working capital 10,427 2,944 10,674
Working capital ratio 11.1:1 3.6:1 8.9:1
Cash and cash equivalents 7,647 1,005 5,847
Total assets 39,873 50,945 44,957
Long-term debt – – –
Trailing twelve-month (TTM)
cash EBITDA (b) 10,183 15,627 9,119
Shareholders’ equity 34,843 43,341 38,646
—————————————————————————-

/T/

(a) The Company’s continuous disclosure documents provide discussion and
analysis of “cash EBITDA”, “cash EBITDA per share”, “shareholder free cash
flow” and “shareholder free cash flow per share”. These financial measures do
not have standard definitions prescribed by IFRS and, therefore, may not be
comparable to similar measures disclosed by other companies. The Company has
included these non-GAAP financial measures because management, investors,
analysts and others use them as measures of the Company’s financial
performance. The Company’s definition of cash EBITDA is cash available for
interest payments, cash taxes if applicable, repayment of debt, purchase of its
shares, discretionary capital expenditures and the payment of dividends (if
applicable), and is calculated as earnings (loss) from operations before
interest, taxes, depreciation and amortization less participation survey
revenue, plus any non-cash and non-recurring expenses. Cash EBITDA excludes
participation survey revenue as these funds are directly used to fund specific
participation surveys and this revenue is not available for discretionary
capital expenditures. The Company believes cash EBITDA assists investors in
comparing Pulse’s results on a consistent basis without regard to participation
survey revenue and non-cash items, such as depreciation and amortization, which
can vary significantly depending on accounting methods or non-operating factors
such as historical cost. Cash EBITDA per share is defined as cash EBITDA
divided by the weighted average number of shares outstanding for the period.
Shareholder free cash flow further refines the calculation of capital available
to invest in growing the Company’s 2D and 3D seismic data library, to repay
debt, to purchase its common shares and to pay dividends (if applicable) by
deducting non-discretionary expenditures from cash EBITDA. Non-discretionary
expenditures are defined as debt financing costs (net of deferred financing
expenses amortized in the current period) and current tax provisions.
Shareholder free cash flow per share is defined as shareholder free cash flow
divided by the weighted average number of shares outstanding for the period.

(b) TTM cash EBITDA is defined as the sum of the trailing 12 months’ cash
EBITDA and is used to provide a comparable annualized measure.

OUTLOOK

Pulse remains cautiously optimistic for an improvement in 2017 while still not
predicting an imminent rebound in its business. Signs for medium to longer-term
optimism are observed in various industry benchmarks and activities.

At US$52.41 per bbl WTI as of April 19, crude oil prices have maintained levels
that are economic for many producers. At Cdn$2.69 per mcf at AECO as of April
19, natural gas prices remain relatively weak, but gas demand continues to grow
and North America’s long supply glut is tightening.

Spending on mineral rights has increased year-over-year, with $93.9 million in
bonus bids in Alberta as of March 23, compared to $34.4 million at this time
last year, and $63.06 million in British Columbia as of April 21 compared to
only $2.1 million by the same point last year. In January, the Petroleum
Services Association of Canada increased its drilling forecast by nearly 1,000
wells to 5,200 wells for 2017. Additional outside capital appears to be flowing
into the oil and gas industry, including through a number of recent initial
public offerings, signaling optimism among operators and investors.

Pulse’s revenue visibility is poor as always. The Company believes that a
recovery in its traditional data library sales depends on materially increased
capital investment and higher field activity by the oil and gas industry on a
sustained basis. Accordingly, Pulse anticipates the possibility of continued
weakness in traditional sales for the short term, followed by a gradual and/or
extended recovery.

Pulse is positioned to grow. Pulse is debt-free, with cash reserves, unutilized
credit facilities, an experienced management team and Board of Directors,
annual cash costs below $6 million, and a valuable, competitive and technically
high-quality asset – its seismic data library. Pulse continues to be a
pure-play seismic data provider with the goal to become the largest licensable
seismic dataset in Western Canada.

CORPORATE UPDATE

Paul Crilly will be nominated for election to Pulse’s Board of Directors at the
Annual Meeting on May 10, 2017. Mr. Crilly has over 25 years of experience in
the oil field services industry, including senior management experience in the
seismic acquisition industry.

In addition, Peter Burnham is retiring from the Board. Pulse thanks Mr. Burnham
for his valued contributions over the past five years.

CONFERENCE CALL

The Company’s next conference call will be held after the release of its
year-end 2017 results, in March 2018. Should investors or analysts wish to
contact the Company, please feel free to contact Neal Coleman or Pamela Wicks
at the e-mail address or telephone number provided below.

CORPORATE PROFILE

Pulse is a market leader in the acquisition, marketing and licensing of 2D and
3D seismic data to the western Canadian energy sector. Pulse owns the
second-largest licensable seismic data library in Canada, currently consisting
of approximately 28,600 square kilometres of 3D seismic and 447,000 kilometres
of 2D seismic. The library extensively covers the Western Canada Sedimentary
Basin where most of Canada’s oil and natural gas exploration and development
occur.

This document contains information that constitutes “forward-looking
information” or “forward-looking statements” (collectively, “forward-looking
information”) within the meaning of applicable securities legislation.

The Outlook section contains forward-looking information which includes, among
other things, statements regarding:

/T/

— Pulse remains cautiously optimistic for an improvement in 2017 while

still not predicting an imminent rebound in its business;
— Pulse anticipates the possibility of continued weakness in traditional
sales for the short term, followed by a gradual and/or extended
recovery;
— Oil and natural gas prices;
— Oil and natural gas drilling activity and land sales activity;
— Oil and natural gas company capital budgets;
— Future demand for seismic data;
— Future seismic data sales;
— Future demand for participation surveys;
— Pulse’s business and growth strategy; and
— Other expectations, beliefs, plans, goals, objectives, assumptions,
information and statements about possible future events, conditions,
results and performance.

/T/

Undue reliance should not be placed on forward-looking information.
Forward-looking information is based on current expectations, estimates and
projections that involve a number of risks and uncertainties, which could cause
actual results to vary and in some instances to differ materially from those
anticipated in the forward-looking information. Pulse does not publish specific
financial goals or otherwise provide guidance, due to the inherently poor
visibility of seismic revenue.

The material risk factors include, without limitation:

/T/

— Oil and natural gas prices;
— The demand for seismic data and participation surveys;
— The pricing of data library license sales;
— Relicensing (change-of-control) fees and partner copy sales;
— Cybersecurity;
— The level of pre-funding of participation surveys, and the Company’s

ability to make subsequent data library sales from such participation
surveys;
— The Company’s ability to complete participation surveys on time and
within budget;
— Environmental, health and safety risks;
— Federal and provincial government laws and regulations, including those
pertaining to taxation, royalty rates, environmental protection and
safety;
— Competition;
— Dependence on qualified seismic field contractors;
— Dependence on key management, operations and marketing personnel;
— The loss of seismic data;
— Protection of intellectual property rights; and
— The introduction of new products.

/T/

The foregoing list is not exhaustive. Additional information on these risks and
other factors which could affect the Company’s operations and financial results
is included under “Risk Factors” of the Company’s MD&A for the most recently
completed financial year and interim periods. Forward-looking information is
based on the assumptions, expectations, estimates and opinions of the Company’s
management at the time the information is presented.

– END RELEASE – 26/04/2017

For further information:
Neal Coleman
President and CEO
Tel.: 403-237-5559
Toll-free: 1-877-460-5559
OR
Pamela Wicks
VP Finance and CFO
Tel.: 403-237-5559
Toll-free: 1-877-460-5559
E-mail: info@pulseseismic.com
Please visit our website at www.pulseseismic.com

COMPANY:
FOR: PULSE SEISMIC INC.
TSX SYMBOL: PSD
OTCQX SYMBOL: PLSDF

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170426CC0112

Press Release from Marketwired 1-866-736-3779

Raise Production Inc. Announces 2016 Financial Results and Operations Update

April 26, 2017 by The Canadian Press

FOR: RAISE PRODUCTION INC.TSX VENTURE SYMBOL: RPCDate issue: April 26, 2017Time in: 6:57 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 26, 2017) – Raise Production Inc. (TSX
VENTURE:RPC) (“Raise” or the “Company”) has released its financial re…

Antrim Announces Filing of Articles of Dissolution and Update on Distribution

April 26, 2017 by The Canadian Press

FOR: ANTRIM ENERGY INC.

Date issue: April 26, 2017
Time in: 6:29 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 26, 2017) –

NOT FOR DISTRIBUTION TO U.S. NEWS WIRE SERVICES OR DISSEMINATION IN THE U.S.

Antrim Energy Inc. (“Antrim” or the “Company”), announces that the Company has
been formally dissolved effective today. The Company filed its Articles of
Dissolution, and a Certificate of Dissolution was issued on April 26, 2017,
pursuant to the voluntary dissolution procedures under the Business
Corporations Act (Alberta).

The Company’s remaining funds will be distributed (the “Distribution”) to those
persons who were shareholders of the Company at the date of dissolution (the
“Shareholders”). This final distribution to Shareholders will be made through
the Company’s transfer agent, CST Trust Company, at such time as the Company
receives a final Tax Clearance Certificate from the Canada Revenue Agency and
from Alberta Tax and Revenue Administration.

The estimated amount of the Distribution is $0.055 CDN per Common Share(1) (an
increase from the Company’s previous estimate of $0.050 CDN per Common Share)
reflecting positive results from the sale of Antrim’s Ireland subsidiary and
settlement of the Company’s obligations. It is not possible to predict when the
tax clearance certificates will be obtained as their receipt is outside of the
control of the Company. The Company has appointed 2015960 Alberta Ltd. as
administrative agent to co-ordinate effecting the Distribution with CST Trust
Company.

For further information on the background to the dissolution and winding up
process, shareholders are advised to review the information circular of the
Company dated July 26, 2016 available on Antrim’s SEDAR profile at
www.sedar.com. Representatives of the Company will forthwith be filing notice
with the Alberta Securities Commission and the securities commissions in each
of the other Provinces in Canada in which the Company is a reporting issuer,
advising that the Company has been formally dissolved, and requesting that the
Company be removed from the list of reporting issuers. As such, it is not
anticipated that any further continuous disclosure will be filed on behalf of
the Company.

Note:

(1) – per share figures based on 184,731,076 Common Shares outstanding.

Forward-Looking and Cautionary Statements

This press release contains certain forward-looking statements and
forward-looking information which are based on Antrim’s internal reasonable
expectations, estimates, projections, assumptions and beliefs as at the date of
such statements or information. Forward-looking statements often, but not
always, are identified by the use of words such as “seek”, “anticipate”,
“believe”, “plan”, “estimate”, “expect”, “targeting”, “forecast”, “achieve” and
“intend” and statements that an event or result “may”, “will”, “should”,
“could” or “might” occur or be achieved and other similar expressions. These
statements are not guarantees of future performance and involve known and
unknown risks, uncertainties, assumptions and other factors that may cause
actual results or events to differ materially from those anticipated in such
forward-looking statements and information. Antrim believes that the
expectations reflected in those forward-looking statements and information are
reasonable but no assurance can be given that these expectations will prove to
be correct and such forward-looking statements and information included in this
press release should not be unduly relied upon. Such forward-looking statements
and information speak only as of the date of this press release and Antrim does
not undertake any obligation to publicly update or revise any forward-looking
statements or information, except as required by applicable laws.

Forward-looking statements presented in such statements or disclosures may,
among other things, relate to: the timing and completion of the Distribution,
and anticipated tax clearance certificate outcomes in connection with the
Dissolution.

Various assumptions or factors are applied in drawing conclusions or making the
forecasts or projections set out in forward-looking statements. Those
assumptions and factors are based on information currently available to the
Corporation. In some instances, material assumptions and factors are presented
or discussed elsewhere in this press release in connection with the statements
or disclosure containing the forward-looking statements.

Shareholders are cautioned that the following list of material factors and
assumptions is not exhaustive. The factors and assumptions include, but are not
limited to the assumptions made in the “Risks and Uncertainties” section of
Antrim’s Management Discussion & Analysis for Q3 2016 which is available under
the Company’s profile on SEDAR at www.sedar.com.

The forward-looking statements or disclosures in this press release are based
(in whole or in part) upon factors which may cause actual results, performance
or achievements of the Corporation to differ materially from those contemplated
(whether expressly or by implication) in the forward-looking statements. Those
factors are based on information currently available to the Corporation
including information obtained by the Corporation from third party sources.
Actual results or outcomes may differ materially from those predicted by such
statements or disclosures. While the Corporation does not know what impact any
of those differences may have, its business, results of operations, financial
condition and its credit stability may be materially adversely affected.
Factors that could cause actual results, performance, achievements or outcomes
to differ materially from the results expressed or implied by forward-looking
statements include, among other things:

/T/

— the failure to realize the anticipated benefits of the Dissolution and

the Distribution, including as a result of any delay in implementing the
Distribution, or adverse tax consequences for the Corporation which
could reduce the amount of the expected Distribution.

/T/

Readers are also specifically referred to “Dissolution of the Corporation –
Risk Factors” in the Corporation’s Management Information Circular dated July
26, 2016 available on Antrim’s SEDAR profile at www.sedar.com for additional
assumptions and risk factors relating to the proposed Dissolution.

The Corporation cautions shareholders that the above list of risk factors is
not exhaustive. Other factors which could cause actual results, performance,
achievements or outcomes to differ materially from those contemplated (whether
expressly or by implication) in the statements or disclosure containing forward
looking statements are disclosed in the Corporation’s publicly filed disclosure
documents.

The forward-looking statements contained in this analysis are expressly
qualified by this cautionary statement. The Corporation is not obligated to
update or revise any forward-looking statements, whether as a result of new
information, future events or otherwise, except as required by applicable laws.
Because of the risks, uncertainties and assumptions contained herein, readers
should not place undue reliance on forward-looking statements or disclosures.
The foregoing statements expressly qualify any forward looking statements
contained herein.

– END RELEASE – 26/04/2017

For further information:
Anthony Potter
President, Chief Executive Officer & Chief Financial Officer
Antrim Energy Inc
+ 1 403 264 5111
potter@antrimenergy.com

COMPANY:
FOR: ANTRIM ENERGY INC.

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170426CC0108

Press Release from Marketwired 1-866-736-3779

Suncor Energy declares dividend

April 26, 2017 by The Canadian Press

FOR: SUNCOR ENERGY INC.TSX SYMBOL: SUNYSE SYMBOL: SUDate issue: April 26, 2017Time in: 6:15 PM eAttention:
All financial figures are in Canadian dollars
CALGARY, ALBERTA–(Marketwired – April 26, 2017) – Suncor Energy’s Board of
Directors has approved…

Western Energy Services Corp. Releases First Quarter 2017 Financial and Operating Results

April 26, 2017 by The Canadian Press

FOR: WESTERN ENERGY SERVICES CORP.TSX SYMBOL: WRGDate issue: April 26, 2017Time in: 5:28 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 26, 2017) – Western Energy Services
Corp. (“Western” or the “Company”) (TSX:WRG) announces the release of it…

Trinidad Drilling Announces Changes to Management Roles

April 26, 2017 by The Canadian Press

FOR: TRINIDAD DRILLING LTD.
TSX SYMBOL: TDG

Date issue: April 26, 2017
Time in: 5:08 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 26, 2017) –

NOT FOR DISTRIBUTION TO UNITED STATES NEWSWIRE SERVICES OR FOR DISSEMINATION IN
THE UNITED STATES.

Trinidad Drilling Ltd. (TSX:TDG) (“Trinidad” and “the Company”) is pleased to
announce changes to management roles. Adrian Lachance will assume the expanded
role of Chief Operating Officer and Randy Hawkings will assume the new role of
Executive Vice President, US Operations.

“Adrian and Randy bring extensive experience in the oil and gas industry to
their new positions,” said Brent Conway, Trinidad’s President and CEO. “Their
continued contributions to managing our operations and assisting in the future
direction of the Company will be invaluable as we guide Trinidad for success in
the current improving conditions and through future industry cycles.”

Adrian has been with Trinidad for 14 years, most recently as Chief Operating
Officer, US and International. During his career with Trinidad, Adrian has held
various senior positions within the Company, including responsibility for the
Company’s US and international operations, rig design and manufacturing, and
corporate business development. Adrian was a key driver behind the Company’s
successful expansion in to the US in 2005, and continues to be an integral part
of the innovative and unique rig designs that have built Trinidad’s reputation
as a high performance driller. Prior to joining Trinidad, Adrian was the owner
of a private drilling company, Bear Drilling, which was acquired by Trinidad in
2003.

Randy joined Trinidad in 2015 as Executive Vice President, Canadian Operations
and Mexico following the acquisition of CanElson Drilling, where he held the
position of President and CEO. In his new role, Randy will be responsible for
running the Company’s US operations. In addition, he will set up and manage
Trinidad’s performance drilling and technology integration initiatives. Randy
holds a Bachelor of Applied Science degree in Mechanical Engineering from the
University of British Columbia and holds a Professional Engineer designation
with the Association of Professional Engineers, Geologists and Geophysicist of
Alberta.

Trinidad is a corporation focused on sustainable growth that trades on the
Toronto Stock Exchange under the symbol TDG. Trinidad’s divisions currently
operate in the drilling sector of the oil and natural gas industry, with
operations in Canada, the United States and internationally. In addition,
through joint venture arrangements, Trinidad operates drilling rigs in Saudi
Arabia and Mexico, and is currently assessing operations in other international
markets. Trinidad is focused on providing modern, reliable, expertly designed
equipment operated by well-trained and experienced personnel. Trinidad’s
drilling fleet is one of the most adaptable, technologically advanced and
competitive in the industry.

– END RELEASE – 26/04/2017

For further information:
Brent Conway
President & Chief Executive Officer
403-265-6525
OR
Lesley Bolster
Chief Financial Officer
403-265-6525
OR
Lisa Ottmann
Vice President, Investor Relations
403-294-4401
investors@trinidaddrilling.com

COMPANY:
FOR: TRINIDAD DRILLING LTD.
TSX SYMBOL: TDG

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170426CC0094

Press Release from Marketwired 1-866-736-3779

Petrocapita Announces Aggregate Proceeds of $1,338,307.74 From Preferred Trust Units and Class ‘A’ Shares of a Subsidiary (Tied Offering)

April 26, 2017 by The Canadian Press

FOR: PETROCAPITA INCOME TRUSTCSE SYMBOL: PCE.UNCSE SYMBOL: PCE.UN.CNDate issue: April 26, 2017Time in: 4:46 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 26, 2017) – Petrocapita Income Trust
(CSE:PCE.UN)(CSE:PCE.UN.CN) (“Petrocapita”) announce…

Traverse Energy Ltd. Announces Private Placement Financing

April 26, 2017 by The Canadian Press

FOR: TRAVERSE ENERGY LTD.TSX VENTURE SYMBOL: TVLDate issue: April 26, 2017Time in: 4:05 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 26, 2017) – Traverse Energy Ltd. (the
“Corporation”) (TSX VENTURE:TVL) intends to complete a non-brokered pri…

Cuba weathers storm in Venezuela but future looks uncertain

April 26, 2017 by The Canadian Press

HAVANA — Refineries have gone dark. Gas rations have been slashed for hundreds of thousands of state workers. Construction materials are nearly impossible to find.

But Cuba’s hotels and restaurants are packed, major U.S. airlines are adding flights and government stores are full of frozen American chicken and U.S.-made candy. So far, Cuba is weathering the storm as Venezuela’s economy craters and protesters fill its streets to denounce Cuba’s greatest socialist ally.

A much-feared return to Cuba’s post-Soviet “Special Period” of food shortages and blackouts has yet to materialize as energy conservation and a boom in tourism and overseas remittances cushion the blow of a roughly 50 per cent cut in Venezuelan oil aid worth hundreds of millions of dollars a year. Interminable bus lines and long hunts for products like milk, paint and cement seem manageable by comparison with the hunger and hardship of the early 1990s that followed the drastic loss of Soviet bloc aid and subsidies that had propped up Cuba’s economy for decades.

The boom set off by the re-establishment of diplomatic relations with the U.S. in 2015 shows no signs of slacking: About 285,000 American tourists visited in 2016, up 76 per cent from 2015, and the Cuban government says U.S. visitors increased 125 per cent in January. The number of visitors from all countries topped a record 4 million last year and appears on track to top that in 2017.

“So far we aren’t living in the Special Period again and I don’t think we will be,” said Ramon Santana, a 52-year-old bicycle taxi driver. “Before, we depended on a single country but now we’re trading with many. Before, the Soviet Union fell and everyone thought we would die. But we didn’t die. We’re still here.”

Still, Cubans are nervously watching Venezuela for signs of a deeper cut in oil shipments, which are paid for with the services of Cuban state doctors on “missions” in poor Venezuelan neighbourhoods. So far, the Cuban government has funneled nearly all the cuts into the state sector, cutting air conditioning and summer work hours at government offices and, most recently, eliminating the supply of higher-octane “special” gasoline for state employees.

The special gas is entirely imported while regular is maintained through the small but steady domestic oil production on Cuba’s north-central coast, which touches the oil-rich Gulf of Mexico. Owners of modern, fuel-injected cars buy special if they can afford it to prevent the lower-octane fuel from damaging their engines.

High-ranking Cuban public officials often get both government cars and a monthly gasoline ration; their pay of $30 to $40 a month makes it impossible otherwise to afford gas that costs more than $4 a gallon. As in virtually every aspect of the Cuban economy, special gas cards provided to state employees to buy the fuel fed a thriving black market. Throughout the day, state officials can be seen filling the tanks of their government car, then popping the pump nozzle into a used 2-litre soft drink bottle and filling it with gas to be sold at a discount to other drivers.

Starting April 1, state gas stations were instructed to stop selling special gas to card-holders, a move that sent state employees to regular pumps, forced business people and diplomats to buy special gas with cash and set off shortage fears and panic buying that created several days of hours-long lines.

Many gas stations around the capital appear to have permanently stopped selling even regular gasoline, their pumps blocked off by orange traffic cones. The column of black smoke from one of Cuba’s main refineries, the Nico Lopez facility overlooking Havana Bay, has disappeared without explanation, leaving the skies clearer but residents worried about Cuba’s future energy supplies.

The replacement of oil money with tourism dollars has accelerated both the decline of Cuba’s ailing state-run businesses and the growth of its small private sector. Whereas oil money went entirely to the Communist state, much of the tourism is going to private enterprise — taxi drivers, private restaurants and bed-and-breakfasts that provide higher value service to tourists trying to avoid the high prices and poor service at state-run eateries and hotels.

“Those who work in the private sector have, in one way or another, seen improvement in their quality of life,” said Omar Everleny Perez, a Cuban economist and expert on the private sector. “The state worker on a salary hasn’t seen that.”

There’s also a geographic disparity, with rural areas and towns that don’t draw tourists seeing deeper, more protracted shortages.

In Cuba, there’s a widespread sense that deeper cuts in Venezuelan oil would push the entire country over the edge into intolerable economic problems.

A near-constant refrain is that Cubans can tolerate deep deprivation, but would not stand for a repeat of the Special Period. On Aug. 5, 1994, at the depth of post-Soviet crisis, Havana residents clashed with police around the Malecon seaside promenade in civil unrest that only subsided after Fidel Castro rushed to the scene and called for the protests to end.

Fidel’s brother and successor, President Raul Castro, has announced that he will step down from the presidency in February 2018. His most likely successor appears to be his first vice-president, 56-year-old Communist Party official Miguel Diaz-Canel, but the government has said nothing about the handover process. Cubans are highly skeptical that a new leader without the credibility conferred by the Castros’ founding role in the Cuban revolution will be able to guide an increasingly well-informed and worldly population through a new period of profound economic hardship.

“If Venezuela falls, if Venezuela changes and they don’t send Cuba any more oil, it’s going to be like it was, in 1991, ’92, ’93. It’s going to be hard,” said Li Nelson Florentino Abreu, an 80-year-old retired electrical engineer. “And Cubans aren’t sheep. They aren’t going to put up with everything. Cubans today, they know how to defend their rights.”

___

Michael Weissenstein on Twitter: https://twitter.com/mweissenstein

Michael Weissenstein, The Associated Press

Loon Energy Corporation: Shares for Debt

April 26, 2017 by The Canadian Press

FOR: LOON ENERGY CORPORATION
TSX VENTURE SYMBOL: LNE.H
NEX BOARD SYMBOL: LNE.H

Date issue: April 26, 2017
Time in: 2:15 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 26, 2017) – Loon Energy Corporation
(NEX:LNE.H) (“Loon” or the “Company”) announces its intention to issue
3,989,243 common shares at the deemed price of $0.05 per common share required
by Exchange regulations to settle outstanding debt of CDN$199,477.15. No
warrants or other convertible securities are to be issued in association with
this settlement. The Company currently has 19,949,136 common shares issued and
outstanding and will have 23,938,379 issued and outstanding after the issuance.
All of the shares are being issued to insiders of the Company.

– END RELEASE – 26/04/2017

For further information:
Loon Energy Corporation
Norman W. Holton
President & Chief Executive Officer
(403) 875-2008
nholton@loonenergy.com

COMPANY:
FOR: LOON ENERGY CORPORATION
TSX VENTURE SYMBOL: LNE.H
NEX BOARD SYMBOL: LNE.H

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170426CC0069

Press Release from Marketwired 1-866-736-3779

Shoal Point to submit Summary Planning Document to regulators

April 26, 2017 by The Canadian Press

FOR: SHOAL POINT ENERGY LTD.CSE SYMBOL: SHPCSE SYMBOL: SHP.CNDate issue: April 26, 2017Time in: 1:51 PM eAttention:
VANCOUVER, BRITISH COLUMBIA–(Marketwired – April 26, 2017) – Mark Jarvis, CEO
of Shoal Point Energy Ltd. (CSE:SHP)(CSE:SHP.CN), announ…

Pot Legalization Before Quantifying Impairment Is Reckless for Oil Patch Worker Safety – David Yager – Yager Management

June 30, 2017April 26, 2017 by EnergyNow Media

David Yager – Yager Management Ltd. Oilfield Service Management Consulting – Oil & Gas Writer – Energy Policy Analyst April 26, 2017 If you asked people to identify the safest industry in Alberta it is unlikely they would choose oil and gas. For years employment in the oilfields has been … Read more

The NEW Ban on Hiring Selected Foreign Workers: What Energy Industry Employers Need to Know – Read it HERE

June 28, 2017April 25, 2017 by EnergyNow Media

By Wendy Ferguson – BHRLR, CPHR – Ferguson HR Consulting The Real Data and My Humble Opinion Our provincial government’s latest solution to our unemployment crisis is to roll out a 2-year pilot project called “Alberta’s Employer Liaison Service”. It was announced last week in Edmonton by the Canadian federal … Read more

“Introduction to the Downstream Industry” – PEICE’s popular course available Virtually on May 1 & 2nd

June 28, 2017April 25, 2017 by EnergyNow Media

PEICE will be offering its popular two-day “Introduction to the Downstream Industry” as Live Virtual Training on May 1 & 2nd. This two-day course has been designed for downstream (refining, transportation, and marketing) sector employees, suppliers, government regulators, industrial petroleum buyers, or others interested in gaining a broad understanding of the refining, supply, and marketing … Read more

Disposition of Common Shares in the Capital of Point Loma Resources Ltd. by Madalena Energy Inc.

April 25, 2017 by The Canadian Press

FOR: MADALENA ENERGY INC.
Date issue: April 25, 2017Time in: 7:18 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 25, 2017) –
NOT FOR DISSEMINATION IN THE UNITED STATES. ANY FAILURE TO COMPLY WITH THIS
RESTRICTION MAY CONSTITUTE A VIOLATION OF U…

Canadian Equipment Rentals Corp. Announces 2016 Year End Results

April 25, 2017 by The Canadian Press

FOR: CANADIAN EQUIPMENT RENTALS CORP.
TSX VENTURE SYMBOL: CFL

Date issue: April 25, 2017
Time in: 7:12 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 25, 2017) – Canadian Equipment Rentals
Corp. (the “Company”) (TSX VENTURE:CFL) today announced its financial and
operating results for the year ended December 31, 2016.

Highlights

Amounts in the following tables are presented in thousands of dollars, except
for per share amounts and percentages.

/T/

—————————————————————————-
—————————————————————————-

Three months ended Twelve months ended
December 31 December 31
(in $000s) 2016 2015 2016 2015
—————————————————————————-
Revenue 3,444 2,426 10,598 17,438
Adjusted EBITDA(1,2) 505 959 2,347 10,914
Adjusted EBIT(1,2) (4,065) (1,740) (20,213) (303)
Net loss from continuing
operations (3,106) (16,032) (19,617) (29,520)
Net (loss) income per share from
continuing operations
Basic ($0.08) ($0.44) ($0.49) ($0.81)
Diluted ($0.08) ($0.44) ($0.49) ($0.81)
Dividends declared – – – 5,808
—————————————————————————-
Amounts in table represents continuing operations, which are comprised of
the Energy Services segment and Corporate
(1) Adjusted for severances and business acquisition costs
(2) See Financial Measures Reconciliations below

/T/

SELECT FINANCIAL RESULTS

/T/

— On February 2, 2016, the Company acquired all the outstanding common and

preferred shares of Zedcor Oilfield Rentals Ltd., a private oilfield
equipment rental company with operations in Western Canada. This
transaction added premier equipment rental assets with an average age of
approximately three years and expanded the Company’s geographic
footprint and customer base. The acquisition was financed through a
combination of the issuance of $4.7 million common and preferred shares,
the payout of $12.8 million in debt and the issuance of a subordinated
vendor take-back note with a fair value of $3.7 million.
— On May 6, 2016, the Company completed the acquisition of all the assets
used in the business of Summit Star Energy Services Inc. (“Summit
Star”). The Company issued 1,713,318 common shares for the assets of
Summit Star, which when multiplied by the volume weighted average price
of the common shares of the Company over the 30 preceding trading days
resulted in a stated purchase price of $0.8 million. The market closing
price of $0.40 per share on the acquisition date was used to value the
1,713,318 common shares, resulting in the recorded purchase price of
$0.7 million.
— On November 17, 2016, the Company announced it signed a share purchase
agreement to sell its Waste Management operating segment to a private
Canadian waste management and recycling services company. The
transaction closed December 1, 2016 and net proceeds of $11.5 million
were used to pay down senior debt.
— On January 31, 2017, the Company announced that it had entered into an
asset purchase agreement with Cooper Rentals Canada Inc. to sell all the
assets of 4-Way Equipment Rentals. The transaction closed on February 9,
2017. Net proceeds were used to pay down senior debt. As at December 31,
2016 the assets and liabilities related to the sale were classified as
held for sale and an impairment of $3.9 million was recognized.
— Both the Waste Management and General Rentals segments were classified
as discontinued operations as at December 31, 2016. As a result, their
financial results are reported separately from continuing operations on
the statement of comprehensive income. The comparative statements of
comprehensive income is re-presented as if the operation had been
discontinued from the start of the comparative year.
— Revenues for the quarter ended December 31, 2016 increased by $1.0
million or 42% from $2.4 million to $3.4 million compared to the similar
quarter in 2015. This is attributable to the acquisition of Zedcor
Oilfield Rentals Ltd. in the first quarter of 2016, along with an
increase in utilization rates quarter over quarter.
— Net loss for the quarter ended December 31, 2016 decreased by $12.9
million from a loss of $16.0 million to a loss of $3.1 million compared
to the similar quarter in 2015. Of the $16.0 million loss in the fourth
quarter of 2015, $14.0 million is a result of goodwill impairment
recognized in the Energy Services business due to significant decline in
revenues from that segment.
— Adjusted EBITDA for the quarter ended December 31, 2016 decreased by
$454,000 or 47% from $959,000 to $505,000 compared to the similar
quarter in 2015. This decrease is a result of increased general and
administrative costs due to the acquisition of Zedcor Oilfield Rentals
Ltd.
— For the year ended December 31, 2016, revenues decreased by $6.8 million
or 39% from $17.4 million to $10.6 million compared to the year ended
December 31, 2015. In direct relation, Adjusted EBITDA decreased by $8.6
million from $10.9 million to $2.3 million. Although commodity prices
started to improve slightly in the latter half of the year, the low
crude oil and natural gas price environment continues to have a negative
impact on the oil and gas sector and demand for rental equipment. The
Energy Services segment continued to see historically low rental rates
in 2016.
— During the year the Company decided to sell certain under-utilized and
obsolete rental assets in both the General Rentals and Energy Services
segment. An impairment of $5.6 million was recognized in the first
quarter and an additional impairment of $2.4 million was recognized in
the third quarter. As at December 31, 2016 all under-utilized equipment
held for sale had been sold.
— For the both the quarter ended September 30, 2016 and December 31, 2016,
the Company was in breach of its financial leverage and interest
coverage covenants as defined in the April 28, 2016 Third Amending
Credit Agreement, which resulted in a default of the senior credit
covenants. See further details in Liquidity and Capital Resources
section below.

/T/

SELECT OPERATING RESULTS

Energy Services Division

/T/

— The Energy Services segment includes the aggregate operations of TRAC

Energy Services Ltd. and Zedcor, which now operates as Zedcor Energy
Services Corp. and represents 100% of the Company’s continuing
operations.
— For the quarter ended December 31, 2016, Energy Services revenues
increased by $1.0 million or 42% compared to the similar period in 2015.
This revenue increase is due in part to the acquisition of Zedcor
Oilfield Rentals Ltd. and in part to improved utilization rates.
— Direct operating costs, excluding depreciation, were reduced by
$258,000, or 15%, for the quarter ended December 31, 2016 compared to
the quarter ended December 31, 2015 due to numerous cost saving
initiatives. These cost saving initiatives included reduction of
headcount, reduced labor hours, a 5% division wide salary decrease and
consolidation of operating facilities. Quarter over quarter depreciation
expense increased by $0.8 million due to the aggregate $23.5 million
Zedcor Oilfield Rentals Ltd. and Summit Star fixed asset acquisitions
early in 2016.
— The resulting margin for the quarter ended December 31, 2016, increased
to 1% compared to negative 34% for the comparative quarter in 2015.
— For the year ended December 31, 2016, revenues declined by $6.8 million
or 39% compared to the year ended December 31, 2015, due to
significantly depressed day rates resulting from increased competition
arising from reduced industry activity.
— For the year ended December 31, 2016, direct costs excluding
depreciation decreased by $5.8 million or 55% from $10.3 million in 2015
to $4.6 million in 2016. This was a direct result of decreased revenue
and cost saving initiatives.
— Depreciation for the year ended December 31, 2016 increased by $1.8
million from $6.0 million to $7.8 million compared to the year ended
December 31, 2015. The increase in depreciation is a result of the
increase in asset base from the acquisition of Zedcor Oilfield Rentals
and Summit Star assets. As a result margins for the year ended December
31, 2016 decreased to negative 16% compared to 6% for December 31, 2015.

/T/

General Rentals Division

/T/

— For the year ended December 31, 2016 and 2015, the General Rentals

segment has been classified as a discontinued operation in the statement
of comprehensive income. General rentals revenue represented 25% of
total revenues of the Company for the quarter and year ended December
31, 2016.
— For the quarter ended December 31, 2016, General Rental revenue declined
by $1.7 million or 48% compared to the quarter ended December 31, 2015.
For the year ended December 31, 2016, revenue decreased similarly by 50%
compared to the year ended 2015. The decrease results from the overall
weak Alberta economy driven by significant declines in oil and gas
prices which has negatively affected industrial activity and increased
competition from new entrants into the local market. For the General
Rentals segment, this has specifically reduced utilization of the
equipment fleet and depressed day rate pricing because of lower demand
for industrial rental equipment coupled with increased competition. Weak
demand for equipment and high competition from other service providers
with idle assets led to aggressive pricing measures, decreasing
operating margins year over year.
— Direct costs and depreciation of operating assets decreased by 40% for
the quarter ended December 31, 2016 and 33% for the year ended December
31, 2016, as a direct result of the decrease in revenues for the same
quarter. Depreciation expense for the quarter ended December 31, 2016
decreased by $162,000 or 16% over the same period in 2015 resulting from
the sale of underutilized assets during the year.

/T/

Waste Management Division

/T/

— For the years ended December 31, 2016 and 2015, the Waste Management

segment has been classified as a discontinued operation in the statement
of comprehensive income. The segment was sold on December 1, 2016,
therefore the results reported are for the two months ended November 30,
2016 and the eleven months ended November 30, 2016. As the Waste
Management segment was classified as held for sale on September 30,
2016, no depreciation was recognized for October and November 2016
resulting in lower depreciation of operating assets and higher margins
for 2016.

/T/

SELECTED QUARTERLY FINANCIAL INFORMATION

/T/

—————————————————————————-
—————————————————————————-

Dec Sept June Mar
31 30 30 31
(Unaudited – in $000s) 2016 2016 2016 2016
—————————————————————————-
Revenue 3,444 2,374 1,469 3,311
Net income (loss) from
continuing operations (3,106) (8,680) (4,683) (3,148)
Net income (loss) from
discontinued operation (3,062) (904) (92) (954)
Adjusted EBITDA(1) 505 461 294 1,131
Adjusted EBITDA per share
– basic(1) 0.01 0.01 0.01 0.03
Net income (loss) per share from
continuing operations
Basic (0.08) (0.21) (0.12) (0.08)
Diluted (0.08) (0.21) (0.12) (0.08)
Net income (loss) per share from
discontinued operation
Basic (0.07) (0.02) 0.00 (0.02)
Diluted (0.07) (0.02) 0.00 (0.02)
Adjusted free cash flow(1) 386 (1,807) 1,011 3,112
—————————————————————————-
—————————————————————————-
(1 ) See Financial Measures Reconciliations below

—————————————————————————-
—————————————————————————-

Dec Sept June Mar
31 30 30 31
(Unaudited – in $000s) 2015 2015 2015 2015
—————————————————————————-
Revenue 2,426 2,954 2,384 9,673
Net income (loss) from
continuing operations (16,032) (12,893) (1,387) 1,150
Net income (loss) from
discontinued operation (659) 254 (579) 453
Adjusted EBITDA(1) 959 3,012 1,274 6,048
Adjusted EBITDA per share
– basic(1) 0.03 0.08 0.03 0.17
Net income (loss) per share from
continuing operations
Basic (0.44) (0.35) (0.04) 0.03
Diluted (0.44) (0.35) (0.04) 0.03
Net income (loss) per share from
discontinued operation
Basic (0.02) 0.01 (0.02) 0.01
Diluted (0.02) 0.01 (0.02) 0.01
Adjusted free cash flow(1) (6) (690) 2,675 3,442
—————————————————————————-
—————————————————————————-
(1 ) See Financial Measures Reconciliations below

/T/

LIQUIDITY AND CAPITAL RESOURCES

On April 28, 2016, the Company’s Syndicated Bank Credit Facility was amended
under the Third Amending Agreement to amend the Debt to EBITDA and Interest
Coverage ratios as follows.

/T/

Mar 31 June 30 Sept 30 Dec 31 Mar 31
Third Amending Agreement 2016 2016 2016 2016 2017 Thereafter
—————————————————————————-
Debt/EBITDA 5.75:1 5.50:1 5.50:1 4.00:1 3.50:1 3.00:1
Interest Coverage 3.25:1 3.25:1 2.50:1 2.75:1 3.25:1 3.50:1

/T/

For the quarter ended September 30, 2016, the Company was in breach of its
financial leverage and interest coverage covenants included in the April 28,
2016 Third Amending Credit Agreement. A breach constitutes an event of default
under the Agreement, which provides the lenders several alternatives including
a waiver of the breach, an amendment to the Agreement to reset the covenants or
a requirement to repay the borrowings.

On November 24, 2016, the Company signed a Fourth Amending Agreement in which
the lenders agreed to forbear from demanding repayment or enforcing its
security under the Agreement. Under the terms of the amending agreement the
authorized amount of the revolving facility was reduced to $46.1 million, while
the authorized amount of the revolving capex facility remained $6.5 million.

On December 15, 2016 the Company’s Syndicated Bank Credit Facility was amended
under the Fifth Amending agreement. The fifth amending agreement included a
reduction in the revolving facility amount from $46 million to $32.5 million
and cancellation of the term facility commitment and operating facility.

Interest payable on all loans drawn under the credit facilities will range from
bank prime rate plus 300 bps to bank prime rate plus 600 bps depending on the
Company’s Debt to EBITDA ratio. Under the terms of the Fifth Amending Credit
Agreement, the Company was not in compliance of its financial leverage and
interest coverage covenants as at December 31, 2016 and all debt held with the
creditors is classified as current.

On February 16, 2017, the Company’s Syndicated Credit Facility was amended
under the Sixth Amending Agreement in which the lenders agree to forbear from
demanding repayment or enforcing its security under the agreement until April
28, 2017.

On April 21, 2017, the Company entered into a Loan and Security Agreement with
a new lender. The Loan and Security Agreement in the amount of $20.4 million
will be used to repay the existing Syndicated Credit Facility, will bear
interest at a rate of 12.75% and has a term of 12 months with an option to
extend for an additional 12 months at the satisfaction of the lender. The Loan
and Security Agreement will be serviced by six months of interest only
payments, followed by six months of blended principal and interest payments.
The Loan and Security Agreement does not require quantitative financial
covenants, but imposes restrictions on the Loan’s collateral, being the
property and equipment of the Company. The Company shall issue the lender share
purchase warrants entitling the lender to acquire common shares in the Company
representing approximately 6.5% of the fully diluted equity at the time of
exercise, at an exercise price of $0.25 per warrant. The warrants will expire
90 days after the term of the loan.

OUTLOOK

2016 has been a pivotal year for Canadian Equipment Rentals Corp. The
acquisition of Zedcor Oilfield Rentals Ltd. (“Zedcor”) and the subsequent
divestitures of MCL Waste Systems & Environmental Inc. and 4-Way Equipment
Rentals Corp., has repositioned the Company as one of the leading oilfield
surface equipment rental companies in the Western Canadian Sedimentary Basin.

As previously announced, the Company has signed a new Loan and Security
Agreement, the proceeds of which will be used to repay the existing lenders. In
conjunction with this refinancing, the Company is retiring $2.5 million of the
Vendor Take Back Note in exchange for 10 million common shares. With this
transaction and the refinancing, the directors of the Company will be
appointing two new directors who will be of great value to the Company.

Through the restructuring efforts over the past six months, including
significant reductions in headcount at the executive level and reductions in
associated discretionary spending, the Company now has a lean operating
structure that can support the full utilization of the existing rental asset
base. This structure, coupled with superior operational performance, service
quality and a best-in-class equipment rental fleet are instrumental to
maintaining and growing market share.

Drilling activity through the first quarter of 2017 has been stronger than
expected which in turn has resulted in improved utilization. Activity in the
second quarter of 2017 currently appears to also be stronger than the same
period in the prior year. This improvement in demand for rental equipment
should begin to drive improvements in equipment rental rates.

The Company continues to expand its market reach and customer base from beyond
its traditional upstream energy services customers to new industry segments
including industrial facilities and pipeline construction. This should lead to
more diversity in its revenue streams and increase the utilization of existing
rental equipment by penetrating new market segments that are less affected by
seasonal fluctuations.

NON-IFRS MEASURES RECONCILIATION

The Company uses certain measures in this MD&A which do not have any
standardized meaning as prescribed by International Financial Reporting
Standards (“IFRS”). These measures which are derived from information reported
in the consolidated statements of operations and comprehensive income may not
be comparable to similar measures presented by other reporting issuers. These
measures have been described and presented in this MD&A in order to provide
shareholders and potential investors with additional information regarding the
Company.

Investors are cautioned that EBITDA, adjusted EBITDA and adjusted EBITDA per
share, adjusted free cash flow and payout ratio are not acceptable alternatives
to net income or net income per share, a measurement of liquidity, or
comparable measures as determined in accordance with IFRS.

EBITDA and Adjusted EBITDA

EBITDA refers to net income before finance costs, income taxes, depreciation,
amortization, and gains or losses on disposal of property and equipment.
Adjusted EBITDA is calculated as EBITDA before costs associated with business
acquisition costs and share based compensation. These measures do not have a
standardized definition prescribed by IFRS and therefore may not be comparable
to similar captioned terms presented by other issuers.

Management believes that EBITDA and Adjusted EBITDA are useful measures of
performance as they eliminate non-recurring items and the impact of finance and
tax structure variables that exist between entities. “Adjusted EBITDA per share
– basic” refers to Adjusted EBITDA divided by the weighted average basic number
of shares outstanding during the relevant periods.

A reconciliation of net income to Adjusted EBITDA is provided below:

/T/

—————————————————————————-
—————————————————————————-

Three months ended Twelve months ended
December 31 December 31
(in $000s) 2016 2015 2016 2015
—————————————————————————-
Net loss from continuing
operations (3,106) (16,032) (19,617) (29,520)
Add:
Finance costs 327 119 1,046 397
Depreciation 2,932 1,505 7,887 6,119
Amortization of intangibles 165 357 661 1,427
Impairment of property and
equipment 21 – 7,822 –
Impairment of intangibles and
goodwill – 13,983 – 26,529
Loss on sale of equipment 672 – 9,878 –
Purchase gain – – (2,664) –
Income taxes (recovery) (1,246) (847) (7,126) (1,726)
Discontinued operation 244 896 2,190 6,342
—————————————————————————-
EBITDA 9 (19) 77 9,568
—————————————————————————-
Add:
Stock based compensation 15 38 136 151
Severance costs 481 923 1,662 1,133
Business acquisition costs – 17 472 62
—————————————————————————-
Adjusted EBITDA 505 959 2,347 10,914
—————————————————————————-
—————————————————————————-

/T/

Adjusted EBIT

Adjusted EBIT refers to earnings before interest and finance charges, taxes,
amortization, impairment of intangibles, purchase gain, other gain, severance
costs and business acquisition costs.

A reconciliation of net income to Adjusted EBIT is provided below:

/T/

—————————————————————————-
—————————————————————————-

Three months ended Twelve months ended
December 31 December 31
(in $000s) 2016 2015 2016 2015
—————————————————————————-
Net loss from continuing
operations (3,106) (16,032) (19,617) (29,520)
Add:
Finance costs 327 119 1,046 397
Amortization of intangibles 165 357 661 1,427
Impairment of property and
equipment 21 – 7,822 –
Impairment of intangibles and
goodwill – 13,983 – 26,529
Purchase gain – – (2,664) –
Income taxes (recovery) (1,246) (847) (7,126) (1,726)
Severance costs 478 845 1,156 903
Business acquisition costs – 17 472 62
Discontinued operation (704) (182) (1,963) 1,625
—————————————————————————-
Adjusted EBIT (4,065) (1,740) (20,213) (303)
—————————————————————————-
—————————————————————————-

/T/

No Conference Call

No conference call will be held in conjunction with this release. Full details
of the Company’s financial results, in the form of the consolidated financial
statements and notes for the year ended December 31, 2106 and Management’s
Discussion and Analysis of the results are available on SEDAR at www.sedar.com
and on the Company’s website at www.cercorp.ca.

About Canadian Equipment Rentals Corp.

Canadian Equipment Rentals Corp. is a Canadian public corporation and parent
company to Zedcor Energy Services Corp. (“Zedcor”). Zedcor is engaged in the
rental of surface equipment and accommodations to the Western Canadian Oil and
Gas Industry. The Company trades on the TSX Venture Exchange under the symbol
“CFL”.

FORWARD-LOOKING STATEMENTS

Certain statements included or incorporated by reference in this press release
constitute forward-looking statements or forward-looking information, including
management’s belief that improvement in demand should begin to drive
improvements in equipment rental rates and that the expanded market reach and
customer base will lead to more diversity in the Company’s revenue stream and
increase utilization. Forward-looking statements or information may contain
statements with the words “anticipate”, “believe”, “expect”, “plan”, “intend”,
“estimate”, “propose”, “budget”, “should”, “project”, “would have realized’,
“may have been” or similar words suggesting future outcomes or expectations.
Although the Company believes that the expectations implied in such
forward-looking statements or information are reasonable, undue reliance should
not be placed on these forward-looking statements because the Company can give
no assurance that such statements will prove to be correct. Forward-looking
statements or information are based on current expectations, estimates and
projections that involve a number of assumptions about the future and
uncertainties. These assumptions include that the Company’s cost cutting
measures that have been implemented will protect future margins and that the
Company’s lean operations will protect against profound down swings in the
economic environment. Although management believes these assumptions are
reasonable, there can be no assurance that they will be proved to be correct,
and actual results will differ materially from those anticipated. For this
purpose, any statements herein that are not statements of historical fact may
be deemed to be forward-looking statements. The forward-looking statements or
information contained in this press release are made as of the date hereof and
the Company assumes no obligation to update publicly or revise any
forward-looking statements or information, whether as a result of new contrary
information, future events or any other reason, unless it is required by any
applicable securities laws. The forward-looking statements or information
contained in this press release are expressly qualified by this cautionary
statement.

– END RELEASE – 25/04/2017

For further information:
Canadian Equipment Rentals Corp.
Ken Olson
Chief Financial Officer
(403) 930-5434
kolson@cercorp.ca

COMPANY:
FOR: CANADIAN EQUIPMENT RENTALS CORP.
TSX VENTURE SYMBOL: CFL

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170425CC0104

Press Release from Marketwired 1-866-736-3779

ATCO Builds Momentum in Global Diversification With New Modular Structures Projects

April 25, 2017 by The Canadian Press

FOR: ATCO LTD.
TSX SYMBOL: ACO.X
TSX SYMBOL: ACO.Y

Date issue: April 25, 2017
Time in: 7:03 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 25, 2017) – Today, ATCO announced that
it has been awarded two new permanent modular structures projects in the
education sector, continuing the company’s successful track record of growing
and diversifying its global operations. Leveraging its 70-year history as a
pioneer in temporary and permanent modular construction, ATCO will construct 57
classrooms for the Victoria Department of Education and Training in Australia
and a 130-student permanent modular dormitory for Trinity Western University in
Langley B.C.

“By reigniting our imaginations and refocusing our efforts on expanding our
global footprint, we are creating opportunities to deliver innovative products
and services to customers,” said Steve Lockwood, President & Chief Operating
Officer, ATCO Structures & Logistics. “These projects demonstrate how we are
diversifying our business into various new industries that are experiencing
rapid growth and seek rapid deployment of easily installed, expandable
facilities.”

The award of 57 modular classroom buildings with the State of Victoria’s
Department of Education and Training in Australia is part of a larger
opportunity to supply and install new classrooms, refurbish existing classroom
fleet, demolish and remove redundant buildings and transfer buildings from one
school to another. All 57 buildings will be manufactured prior to the end of
June 2017 and installation will begin once the classrooms are allocated to
eligible schools in September 2017. This program enables the Victoria
Department of Education and Training to manage fluctuations in enrollment
growth throughout the state school system.

ATCO also received a notice to proceed in British Columbia for the design and
build of a 130-student dormitory at Trinity Western University in the first
quarter of 2017. The facility is scheduled for completion by September 2017.
The three-storey dorm is being designed for expansion to accommodate future
growth. Drawing upon the integrated energy expertise of its people, ATCO will
also upgrade the site’s electrical infrastructure.

With approximately 7,000 employees and assets of $20 billion, ATCO is a
diversified global corporation delivering service excellence and innovative
business solutions in Structures & Logistics (workforce housing, innovative
modular facilities, construction, site support services, and logistics and
operations management); Electricity (electricity generation, transmission, and
distribution); Pipelines & Liquids (natural gas transmission, distribution and
infrastructure development, energy storage, and industrial water solutions);
and Retail Energy (electricity and natural gas retail sales). More information
can be found at www.ATCO.com.

– END RELEASE – 25/04/2017

For further information:
Media Inquiries:
Spencer Forgo
Manager, External Communications
(403) 662-8467

COMPANY:
FOR: ATCO LTD.
TSX SYMBOL: ACO.X
TSX SYMBOL: ACO.Y

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Utilities, Manufacturing and Production – Packaging and Containers,
Energy and Utilities – Pipelines
RELEASE ID: 20170425CC0103

Press Release from Marketwired 1-866-736-3779

TODAY! STEP Energy Services – Hiring Fair April 26th in Grande Prairie -DETAILS HERE

June 28, 2017April 25, 2017 by EnergyNow Media

Check out their current opportunities here: stepenergyservices.startdate.ca

Oil pipeline spill pollutes North Dakota tributary

April 25, 2017 by The Canadian Press

BISMARCK, N.D. — A 1,050-gallon oil pipeline spill in western North Dakota polluted a tributary of the Little Missouri River but was prevented from flowing into the larger waterway by its fast-moving current, a state Health Department official said Tuesday.

An estimated 756 gallons of oil and 294 gallons of saltwater, a drilling byproduct, leaked from a pipeline in Bowman County operated by Oklahoma City-based Continental Resources. The spill was discovered Saturday about 5 miles southwest of Marmarth, and more than three-fourths of the mess had been cleaned up as of Sunday.

Health Department environmental scientist Bill Suess was travelling to the site Tuesday and didn’t have an update on cleanup. Continental Resources spokeswoman Kristin Thomas didn’t immediately respond to a request for comment.

The company reported the spill Saturday and state officials went immediately to the site, which is in a remote area with little access, according to the Health Department, which announced the spill Monday afternoon. There was no danger to the public due to the delay, as no one lives in the area and anyone wishing to swim or fish in the creek would have been warned away by company and state officials at the scene, Suess said.

The cause of the leak was unknown, with excavation work still underway. There were no immediate indications of damage to wildlife or livestock, according to Suess.

The spill polluted a 14-mile stretch of Little Beaver Creek. The company believes fewer than 50 gallons made it into the water, with the Health Department estimating about double that, Suess said.

“At the time of the release there was a high-enough flow in the Little Missouri that it was actually pushing water back up into Little Beaver Creek, so that prevented any from getting into the Little Missouri,” Suess said. The Little Missouri is a tributary of the Missouri River.

The oil has a thick consistency that causes it to clump together in the water.

“It forms these little balls and they float down the river,” Suess said. “It’s pretty easy to collect.”

The spill was much smaller than a December leak on the Belle Fourche Pipeline in Billings County that spilled about 530,000 gallons of oil, one of the largest spills in state history. The spill dumped crude into a separate tributary of the Little Missouri River, but not the river itself.

No immediate decisions have been made on any possible fines in either case, Suess said.

___

Follow Blake Nicholson on Twitter at: http://twitter.com/NicholsonBlake

Blake Nicholson, The Associated Press

Pengrowth Enters Into Agreement to Sell Remaining Swan Hills Assets for $185 Million

April 25, 2017 by The Canadian Press

FOR: PENGROWTH ENERGY CORPORATION
TSX SYMBOL: PGF
NYSE SYMBOL: PGH

Date issue: April 25, 2017
Time in: 5:10 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 25, 2017) – Pengrowth Energy Corporation
(TSX:PGF)(NYSE:PGH) (the “Company” or “Pengrowth”) today announced that it has
entered into an agreement for the sale of the remaining portion of its Swan
Hills assets in North Central Alberta for total cash consideration of $185
million, subject to customary closing conditions and adjustments.

The divested assets generated average daily production of approximately 5,150
barrels of oil equivalent per day (boe per day) (weighted approximately 94
percent towards liquids) during the fourth quarter of 2016 and had Proved plus
Probable reserves of 21.0 million boe assigned to them as at December 31, 2016,
according to the independent reserve evaluators GLJ Petroleum Consultants Ltd.

This transaction essentially completes Pengrowth’s exit from the Swan Hills
area and provides the company with additional financial flexibility to further
reduce indebtedness. When combined with the $522 million of proceeds from the
previously announced Lindbergh GORR, Swan Hills and Bernadet asset sales, the
$185 million of proceeds from this sale of the remaining Swan Hills assets
result in total disposition proceeds of $707 million to date in 2017.

The effective date of the sale is January 1, 2017 and closing is expected to
occur on May 31, 2017, subject to the receipt of all necessary regulatory
approvals and the satisfaction of other customary closing conditions.

The Company expects to use the proceeds from this sale to further reduce its
indebtedness, including prepaying the remaining outstanding US $100 million
(equivalent Cdn $134 million) of the 6.35% senior term notes which are
scheduled to mature on July 26, 2017. The prepayment is expected to be
completed before the end of the second quarter following which the Company will
have no further term debt due until August 2018.

Upon closing of all announced dispositions and application of proceeds to debt
repayment, Pengrowth’s debt would fall to approximately Cdn $700 million,
representing a decline in debt levels of approximately 60 percent since
December 31, 2016.

The sale of the remaining Swan Hills assets is expected to impact full year
2017 average production guidance by approximately 3,400 boe per day, resulting
in revised 2017 production to be between 43,500 and 45,500 boe per day. The
remaining changes to 2017 guidance resulting from the sale are outlined in the
table below:

/T/

—————————————————————————-

Previous Guidance Date Guidance
—————————————————————————-
Average daily production (boe per day) 47,000 to 49,000 43,500 to 45,500
—————————————————————————-
Total capital expenditures ($ millions) 125 125
—————————————————————————-
Funds flow from operations(1)($
millions) 170 160
—————————————————————————-
Royalties(2) (% of sales) 9.0 9.0
—————————————————————————-
Operating costs(3) ($ per boe) 13.00 to 13.50 13.00 to 13.50
—————————————————————————-
Cash G & A(3)($ per boe) 3.50 to 4.00 3.50 to 4.00
—————————————————————————-
1. Based on a WTI crude oil price of US $55.00/bbl, an AECO natural gas
price of Cdn $3.25/Mcf and a $0.74 USD/Cdn exchange rate
2. Royalties are before impacts of commodity risk management activities
3. Per boe estimates based on high and low ends of production guidance

/T/

2017 Hedging Update

Prior to the recent strengthening in crude oil prices, Pengrowth elected to
cancel its 2017 light oil risk management contracts it had in place and
presently has no oil production hedged. The Company also entered into new
natural gas risk management contracts to provide downside protection against
potential declines in natural gas prices. As at March 31, 2017, the Company had
the following risk management contracts in place for the remainder of 2017:

/T/

——————————
Natural Gas Q2, 2017 Q3 2017 Q4 2017
—————————————————————————-
Volumes (MMcf/d) 58.3 58.3 22.8
—————————————————————————-
Fixed AECO price (Cdn$/Mcf) $2.72 $2.72 $2.82
—————————————————————————-

/T/

First Quarter 2017 Conference Call

Pengrowth intends to release its first quarter results for the period ending
March 31, 2017 on Tuesday, May 2, 2017, following the close of equity markets.
A conference call and listen only audio webcast will be held, beginning at 6:30
A.M. Mountain Time (MT) on Wednesday, May 3, 2017, during which management will
review Pengrowth’s results and respond to questions from the analyst community.

To ensure timely participation in the teleconference, callers are encouraged to
dial in 10 minutes prior to the start of the call to register.

Dial-in numbers:

Toll free: (844) 358-9179 or International (478) 219-0186

Live listen only audio webcast: http://edge.media-server.com/m/p/6qtxx6m4

The call will be recorded and available for playback shortly after the
conclusion of the meeting using the following dial-in numbers:

(855) 859-2056 or (800) 585-8367

Conference ID: 7764789

Advisors

BMO Capital Markets Inc. acted as financial advisors to Pengrowth on the
transaction.

About Pengrowth:

Pengrowth Energy Corporation is a Canadian intermediate energy company focused
on the sustainable development and production of oil and natural gas in Western
Canada. The Company is headquartered in Calgary, Alberta, Canada and has been
operating in the Western basin for over 28 years. The Company’s shares trade on
both the Toronto Stock Exchange under the symbol “PGF” and on the New York
Stock Exchange under the symbol “PGH”.

PENGROWTH ENERGY CORPORATION

Derek Evans, President and Chief Executive Officer

Advisories:

Currency:

All amounts are stated in Canadian dollars unless otherwise specified.

Advisory Regarding Reserves and Production Information

All reserves and production information herein is based upon Pengrowth’s
company interest (Pengrowth’s working interest share of reserves or production
plus Pengrowth’s royalty interest, being Pengrowth’s interest in production and
payment that is based on the gross production at the wellhead), before
deduction of royalty obligations and using GLJ’s January 1, 2017 forecast
prices and costs as disclosed herein. Numbers presented may not add due to
rounding.

Caution Regarding Engineering Terms:

When used herein, the term “boe” means barrels of oil equivalent on the basis
of one boe being equal to one barrel of oil or NGLs or 6,000 cubic feet of
natural gas (6 mcf: 1 bbl). Barrels of oil equivalent may be misleading,
particularly if used in isolation. A conversion ratio of six mcf of natural gas
to one boe is based on an energy equivalency conversion method primarily
applicable at the burner tip and does not represent a value equivalency at the
wellhead.

Caution Regarding Forward Looking Information:

In the interest of providing our shareholders and potential investors with
information regarding us, including management’s assessment of our future plans
and operations, certain statements in this press release are forward-looking
statements within the meaning of securities laws, including the “safe harbour”
provisions of the Canadian securities legislation and the United States Private
Securities Litigation Reform Act of 1995. Forward-looking information is often,
but not always, identified by the use of words such as “anticipate”, “believe”,
“expect”, “plan”, “intend”, “forecast”, “target”, “project”, “guidance”, “may”,
“will”, “should”, “could”, “estimate”, “predict” or similar words suggesting
future outcomes or language suggesting an outlook. Forward-looking statements
in this press release include, but are not limited to, expected disposition
proceeds and the application thereof to reduce indebtedness; anticipated
prepayment of remaining term debt due in 2017 and no term debt due until August
2018 following such prepayment; proforma indebtedness, anticipated closing date
and expected 2017 average daily production, capital expenditures, funds flow
from operations, royalties, operating costs and cash G&A. Forward-looking
statements and information are based on current beliefs as well as assumptions
made by and information currently available to Pengrowth concerning anticipated
financial performance, business prospects, strategies and regulatory
developments. Although management considers these assumptions to be reasonable
based on information currently available to it, they may prove to be incorrect.

By their very nature, forward-looking statements involve inherent risks and
uncertainties, both general and specific, and risks that predictions,
forecasts, projections and other forward-looking statements will not be
achieved. We caution readers not to place undue reliance on these statements as
a number of important factors could cause the actual results to differ
materially from the beliefs, plans, objectives, expectations and anticipations,
estimates and intentions expressed in such forward-looking statements. These
factors include, but are not limited to: changes in general economic, market
and business conditions; the volatility of oil and gas prices; fluctuations in
production and development costs and capital expenditures; the imprecision of
reserve estimates and estimates of recoverable quantities of oil, natural gas
and liquids; Pengrowth’s ability to replace and expand oil and gas reserves;
geological, technical, drilling and processing problems and other difficulties
in producing reserves; environmental claims and liabilities; incorrect
assessments of value when making acquisitions; increases in debt service
charges; the loss of key personnel; the marketability of production; defaults
by third party operators; unforeseen title defects; fluctuations in foreign
currency and exchange rates; fluctuations in interest rates; inadequate
insurance coverage; compliance with environmental laws and regulations; actions
by governmental or regulatory agencies, including changes in tax laws;
Pengrowth’s ability to access external sources of debt and equity capital; the
impact of foreign and domestic government programs and the occurrence of
unexpected events involved in the operation and development of oil and gas
properties. Further information regarding these factors may be found under the
heading “Business Risks” in our most recent management’s discussion and
analysis and under “Risk Factors” in our Annual Information Form dated February
28, 2017.

The foregoing list of factors that may affect future results is not exhaustive.
When relying on our forward-looking statements to make decisions, investors and
others should carefully consider the foregoing factors and other uncertainties
and potential events. Furthermore, the forward-looking statements contained in
this press release are made as of the date of this press release, and Pengrowth
does not undertake any obligation to update publicly or to revise any of the
included forward-looking statements, whether as a result of new information,
future events or otherwise, except as required by applicable laws. The
forward-looking statements contained in this press release are expressly
qualified by this cautionary statement.

– END RELEASE – 25/04/2017

For further information:
Wassem Khalil
Manager, Investor Relations
Toll free 1-855-336-8814
OR
Pengrowth
www.pengrowth.com
Investor Relations
E-mail: investorrelations@pengrowth.com

COMPANY:
FOR: PENGROWTH ENERGY CORPORATION
TSX SYMBOL: PGF
NYSE SYMBOL: PGH

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170425CC0095

Press Release from Marketwired 1-866-736-3779

Vantage Drilling International Schedules First Quarter 2017 Earnings Release Date and Conference Call

April 25, 2017 by The Canadian Press

FOR: VANTAGE DRILLING INTERNATIONAL
Date issue: April 25, 2017Time in: 5:00 PM eAttention:
HOUSTON, TX–(Marketwired – April 25, 2017) – Vantage Drilling International
(“Vantage” or the “Company”) today announced that it will host a conference
call at…

Canacol Energy Ltd. Consolidates Core Gas Exploration Position with Acquisition of Operated Interest in the SSJN7 E&P Contract, Lower Magdalena Valley Basin

April 25, 2017 by The Canadian Press

FOR: CANACOL ENERGY LTD.
TSX SYMBOL: CNE
BVC SYMBOL: CNEC
OTCQX SYMBOL: CNNEF

Date issue: April 25, 2017
Time in: 4:30 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 25, 2017) – Canacol Energy Ltd.
(“Canacol” or the “Corporation”) (TSX:CNE)(OTCQX:CNNEF)(BVC:CNEC) is pleased to
announce that it has purchased Pacific Exploration and Production’s (“PEP”) 50%
operated interest in the SSJN7 Exploration and Production (“E&P”) Contract for
a consideration of the assumption of contractual exploration obligations to the
Agencia Nacional de Hidrocarburos (“ANH”), Colombia’s resource administrator.
The agreement is subject to approval by the ANH, which the Corporation expects
to receive within the next 3 to 6 months.

Charle Gamba, President and CEO of Canacol, commented, “The low cost
acquisition of the SSJN7 block continues the consolidation of our core operated
gas exploration and production area in the Lower Magdalena Valley basin,
following the purchase of Shona’s interests in the Esperanza and VIM21 blocks
in 2012, and of OGX’s interests in the VIM5 and VIM19 blocks in 2014. Our
consolidation efforts over the past four years have been both low cost and
successful, with our exploration efforts on those blocks yielding six
commercial gas discoveries containing 318 billion cubic feet of 3P reserves as
represented by the Corporation’s reserve auditors since 2014.

The SSJN7 block occupies a prime central position within our core gas
exploration area, with the block flanked both to the north and to the south by
large producing gas fields and historic commercial gas fields discovered on the
block itself. SSJN7 is located along both the Cienaga de Oro (CDO) and the
Porquero exploration gas play fairways that our management team knows well,
having drilled six commercial gas discoveries in the past four years into these
fairways on the adjacent operated blocks. The block is also situated along the
route of both the existing Promigas pipeline and the planned route for the new
gas pipeline that Canacol is building via a Special Purpose Vehicle. This
ensures that when gas is found on the SSJN7 block it will be quickly and
efficiently commercialized.”

SSJN7 E&P Contract
CNE Oil and Gas S.A.S, 50% Operated WI
335,000 net acres

The SSJN7 Contract is situated between the VIM 5 and VIM19 E&P contracts where
Canacol has a 100% operated working interest acquired from OGX in 2014 (Figure
1). The SSJN7 block is 669,000 gross acres in size, and increases Canacol’s net
exploration acreage position 43% from 785,000 acres to 1,120,000 acres within
the most prolific gas prone and productive part of the Lower Magdalena Valley
basin.

The SSJN7 block is situated along both of the proven and productive CDO and
Porquero gas play fairways, as evidenced by the position of large producing gas
fields both to the north and to the south of the block. Historically, a number
of exploration wells have been drilled, and two commercial discoveries in the
CDO were developed on the block, namely the Chinu (1956) and El Deseo (1989)
fields. At present, Canacol management have identified a number of leads based
on the limited 2D seismic coverage on the block. As part of the future plans
for the block the Corporation will reprocess the existing 2D seismic data
utilizing seismic processing and interpretation techniques to identify
gas-filled reservoirs. The Corporation expects to high-grade prospective areas
on the block for the acquisition of additional 2D and 3D seismic data to
advance the leads to prospect status, and to identify additional leads and
prospects. The Corporation expects to acquire new seismic and drill an
exploration well in the next 18 months.

To view Figure 1, click on the following link:
http://media3.marketwire.com/docs/Canacol425b.jpg

Canacol is an exploration and production company with operations in Colombia,
Ecuador and Mexico. The Corporation’s common stock trades on the Toronto Stock
Exchange, the OTCQX in the United States of America, and the Colombia Stock
Exchange under ticker symbol CNE, CNNEF, and CNE.C, respectively.

This press release contains certain forward-looking statements within the
meaning of applicable securities law. Forward-looking statements are frequently
characterized by words such as “plan”, “expect”, “project”, “intend”,
“believe”, “anticipate”, “estimate” and other similar words, or statements that
certain events or conditions “may” or “will” occur, including without
limitation statements relating to estimated production rates from the
Corporation’s properties and intended work programs, gas pipelines, and
associated timelines. Forward-looking statements are based on the opinions and
estimates of management at the date the statements are made and are subject to
a variety of risks and uncertainties and other factors that could cause actual
events or results to differ materially from those projected in the
forward-looking statements. The Corporation cannot assure that actual results
will be consistent with these forward-looking statements. They are made as of
the date hereof and are subject to change and the Corporation assumes no
obligation to revise or update them to reflect new circumstances, except as
required by law. Prospective investors should not place undue reliance on
forward looking statements. These factors include the inherent risks involved
in the exploration for and development of crude oil and natural gas properties,
the uncertainties involved in interpreting drilling results and other
geological and geophysical data, fluctuating energy prices, the possibility of
cost overruns or unanticipated costs or delays and other uncertainties
associated with the oil and gas industry. Other risk factors could include
risks associated with negotiating with foreign governments as well as country
risk associated with conducting international activities, and other factors,
many of which are beyond the control of the Corporation.

Definitions
Resource definitions, including those set out below, are as specified by NI
51-101, including by reference to CSA Staff Notice 51-324 – Glossary to NI
51-101 Standards of Disclosure for Oil and Gas Activities and the COGE Handbook.

Boe conversion – The term “boe” is used in this news release. Boe may be
misleading, particularly if used in isolation. A boe conversion ratio of cubic
feet of natural gas to barrels oil equivalent is based on an energy equivalency
conversion method primarily applicable at the burner tip and does not represent
a value equivalency at the wellhead. In this news release, we have expressed
boe using the Colombian conversion standard of 5.7 Mcf: 1 bbl required by the
Ministry of Mines and Energy of Colombia.

“3P” means Total Proved + Probable + Possible

“Proved reserves” are those reserves that can be estimated with a high degree
of certainty to be recoverable. It is likely that the actual remaining
quantities recovered will exceed the estimated proved reserves;

“Probable reserves” are those additional reserves that are less certain to be
recovered than proved reserves. It is equally likely that the actual remaining
quantities recovered will be greater or less than the sum of the estimated
proved plus probable reserves;

“Possible reserves” means those additional reserves that are less certain to be
recovered than probable reserves. It is unlikely that the actual remaining
quantities recovered will exceed the sum of the estimated proved plus probable
plus possible reserves;

– END RELEASE – 25/04/2017

For further information:
Investor Relations
214-235-4798
IR@canacolenergy.com
www.canacolenergy.com

COMPANY:
FOR: CANACOL ENERGY LTD.
TSX SYMBOL: CNE
BVC SYMBOL: CNEC
OTCQX SYMBOL: CNNEF

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170425CC0087

Press Release from Marketwired 1-866-736-3779

PrairieSky Announces Results of the Annual Meeting of Shareholders and Election of Directors

April 25, 2017 by The Canadian Press

FOR: PRAIRIESKY ROYALTY LTD.TSX SYMBOL: PSKDate issue: April 25, 2017Time in: 4:01 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 25, 2017) – PrairieSky Royalty Ltd.
(“PrairieSky” or the “Company”) (TSX:PSK) is pleased to announce that its
shar…

Athabasca Oil Corporation Announces Results of Shareholders’ Meeting

April 25, 2017 by The Canadian Press

FOR: ATHABASCA OIL CORPORATION
TSX SYMBOL: ATH

Date issue: April 25, 2017
Time in: 3:56 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 25, 2017) – Athabasca Oil Corporation
(TSX:ATH) (“Athabasca” or the “Company”) is pleased to announce that all
matters presented for approval at the Annual General and Special Meeting of
Shareholders held April 25, 2017 have been fully authorized and approved. The
items on the agenda included fixing the number of directors to be elected at
six, electing six proposed director nominees, approval of the performance award
plan and appointment of Ernst & Young LLP as auditors.

The results of the voting, inclusive of all votes casts and proxies received
for each director nominee, which was conducted by ballot, are as follows:

/T/

—————————————————————————-

Nominee Votes For Votes Withheld
————————————————————
No. % No. %
—————————————————————————-
Ronald Eckhardt 267,606,495 75.32 87,695,731 24.68
—————————————————————————-
Bryan Begley 264,110,910 74.33 91,191,316 25.67
—————————————————————————-
Robert Broen 311,477,358 87.67 43,824,868 12.33
—————————————————————————-
Carlos Fierro 263,831,664 74.26 91,470,562 25.74
—————————————————————————-
Marshall McRae 289,700,459 81.54 65,601,767 18.46
—————————————————————————-
Henry Sykes 291,227,078 81.97 64,075,148 18.03
—————————————————————————-

/T/

About Athabasca Oil Corporation

Athabasca Oil Corporation is a Canadian energy company with a focused strategy
on the development of thermal and light oil assets. Situated in Alberta’s
Western Canadian Sedimentary Basin, the Company has amassed a significant land
base of extensive, high quality resources. Athabasca’s common shares trade on
the TSX under the symbol “ATH”. For more information, visit www.atha.com.

– END RELEASE – 25/04/2017

For further information:
Media and Financial Community
Matthew Taylor
Vice President, Capital Markets and Communications
1-403-817-9104
mtaylor@atha.com

COMPANY:
FOR: ATHABASCA OIL CORPORATION
TSX SYMBOL: ATH

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170425CC0085

Press Release from Marketwired 1-866-736-3779

Encana to hold 2017 first quarter results conference call and Annual Meeting of Shareholders on Tuesday, May 2, 2017

April 25, 2017 by The Canadian Press

FOR: ENCANA CORPORATION
TSX Symbol: ECA
NYSE Symbol: ECA

Date issue: April 25, 2017
Time in: 11:30 AM e

Attention:

CALGARY, AB –(Marketwired – April 25, 2017) – (TSX: ECA) (NYSE: ECA)

Encana Corporation will release its 2017 first quarter results and hold its
Annual Meeting of Shareholders on Tuesday, May 2, 2017. The news release
detailing Encana’s 2017 first quarter results will provide operating and
financial information. Financial statements will be available on the company’s
website.

A conference call and webcast to discuss the 2017 first quarter results will
be held for the investment community the same day at 7 a.m. MT (9 a.m. ET). To
participate, please dial (844) 707-0663 (toll-free in North America) or (703)
326-3003 (international) approximately 10 minutes prior to the conference
call.

The Annual Meeting of Shareholders will be held at the BMO Centre, Palomino
Room, 20 Roundup Way S.E., Calgary, Alberta, beginning at 10 a.m. MT (12 p.m.
ET).

Live audio webcasts of the first quarter conference call and the Annual
Meeting of Shareholders, including slides, will also be available on Encana’s
website, www.encana.com, under Investors/Presentations & Events. The webcasts
will be archived for approximately 90 days.

Encana Corporation

Encana is a leading North American energy producer that is focused on
developing its strong portfolio of resource plays, held directly and
indirectly through its subsidiaries, producing natural gas, oil and natural
gas liquids (NGLs). By partnering with employees, community organizations and
other businesses, Encana contributes to the strength and sustainability of the
communities where it operates. Encana common shares trade on the Toronto and
New York stock exchanges under the symbol ECA.

SOURCE: Encana Corporation

– END RELEASE – 25/04/2017

For further information:

Further information on Encana Corporation is available on the company’s website, www.encana.com, or by contacting:

Investor contact:
Brendan McCracken
Vice-President, Investor Relations
(403) 645-2978

Patti Posadowski
Sr. Advisor, Investor Relations
(403) 645-2252

Media contact:
Simon Scott
Vice-President, Communications
(403) 645-2526

Jay Averill
Director, Media Relations
(403) 645-4747

COMPANY:
FOR: ENCANA CORPORATION
TSX Symbol: ECA
NYSE Symbol: ECA

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170425CC011

Press Release from Marketwired 1-866-736-3779

Troy Energy Corp. Announces Private Placement

April 25, 2017 by The Canadian Press

FOR: TROY ENERGY CORP.NEX BOARD SYMBOL: TEG.HTSX VENTURE SYMBOL: TEG.HDate issue: April 25, 2017Time in: 11:11 AM eAttention:
VANCOUVER, BRITISH COLUMBIA–(Marketwired – April 25, 2017) – Troy Energy Corp.
(the “Corporation” or “Troy”) (NEX:TEG.H) ann…

Augusta Delivers New Portable EFM System

April 25, 2017 by The Canadian Press

FOR: AUGUSTA INDUSTRIES INC.TSX VENTURE SYMBOL: AAODate issue: April 25, 2017Time in: 8:21 AM eAttention:
TORONTO, ONTARIO–(Marketwired – April 25, 2017) – Augusta Industries Inc. (the
“Corporation”) (TSX VENTURE:AAO) is pleased to announce that its …

Jericho Oil Announces 20% Increase in Borrowing Base

April 25, 2017 by The Canadian Press

FOR: JERICHO OIL CORPORATIONTSX VENTURE Symbol: JCOOTC PINK Symbol: JROOFDate issue: April 25, 2017Time in: 8:00 AM eAttention:
TULSA, OK and VANCOUVER, BC –(Marketwired – April 25, 2017) – Jericho Oil
Corporation (“Jericho”) (TSX VENTURE: JCO) (OTC…

Teck Reports Unaudited First Quarter Results for 2017 – Part 8

April 24, 2017 by The Canadian Press

/T/
Copper Unit Cost Reconciliation
/T/
—————————————————————————-
Three months ended March 31,
(CAD$ in millions, except where noted) 20…

Teck Reports Unaudited First Quarter Results for 2017 – Part 9

April 24, 2017 by The Canadian Press

/T/
Teck Resources Limited
Notes to Condensed Interim Consolidated Financial Statements
(Unaudited)
1. BASIS OF PREPARATION
We prepare our annual consolidated financial statements in accordance with
International Financial Reporting Standards (IFRS) a…

Alberta appeal court backs decision that favoured Redwater Energy creditors

April 24, 2017April 24, 2017 by The Canadian Press

CALGARY — A court decision that gave secured creditors priority over environmental cleanup in the case of bankrupt Redwater Energy Corp. has been upheld by the Alberta Court of Appeal.

The lawsuit has been closely watched as a precedent-setting case as bankruptcies continue to afflict the oil and gas industry after more than two years of low commodity prices.

In a 2-1 decision released Monday, the appeal court upheld the ruling in favour of Grant Thornton, Redwater’s trustee in bankruptcy, and its lender, ATB Financial, who wanted to sell off its productive wells to pay creditors and leave the others for the industry-supported Orphan Well Association to remediate.

The Alberta Energy Regulator, however, argued funds from the sale of the productive wells must be used to cover cleanup expenses for the unproductive wells, a position backed by appeal interveners from the Alberta, B.C. and Saskatchewan governments as well as the Canadian Association of Petroleum Producers.

In a statement Monday night, the Alberta Energy Regulator said it is reviewing the decision and determining whether to appeal.

“While we are disappointed in the court’s decision, the AER will continue to take steps to protect the public from the environmental costs associated with suspension, abandonment and reclamation,” spokesman Ryan Bartlett said in the statement.

Brad Herald, chairman of the Orphan Well Association, said there have been other cases since Redwater where a receiver wants to “disclaim” an insolvent company’s liabilities.

He wouldn’t give company names, but said the trend shows the precedent-setting nature of the Redwater decision and suggests further appeal is warranted by the regulator.

“I think the potential of the dissenting opinion here can bolster the justification for resolution to the Supreme Court,” he said.

In a dissenting opinion, however, the third judge argued that the regulations are consistent with the act and said the appeal should be allowed.

A spokesperson for Energy Minister Marg McCuaig-Boyd said the department is analyzing the decision.

“This ruling demonstrates the need to do a thorough review of the oil and gas liability management system that we have inherited,” press secretary Mike McKinnon said in an email. “Our government is beginning this work.”

The regulator had appealed the decision because it said it could encourage more companies to enter receivership and bankruptcy to avoid obligations to clean up oil and gas well sites.

Follow @HealingSlowly on Twitter.

Dan Healing, The Canadian Press

The Digital Oilfield Zone – Don’t Miss the Latest Technology at GPS 2017 – Exhibit & Free to Attend – Information HERE

June 28, 2017April 24, 2017 by EnergyNow Media

The intersection between oil & gas industry and the digital industry has never been more evident than it is today, and its worth billions of dollars to energy operators in cost savings and business efficiencies. Whether it is communications, mobile apps, big data or automation; companies cannot ignore the new era of digital oilfield. The … Read more

Canadian Equipment Rentals Corp. completes restructuring and enters into a new Loan and Security Agreement with Maynbridge Capital Inc.

April 24, 2017 by The Canadian Press

FOR: CANADIAN EQUIPMENT RENTALS CORP.
TSX VENTURE SYMBOL: CFL

Date issue: April 24, 2017
Time in: 7:38 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 24, 2017) – Canadian Equipment Rentals
Corp. (“CERC” or the “Company”) (TSX VENTURE:CFL) is pleased to announce that
it has largely completed its restructuring efforts and entered into a Loan and
Security Agreement with Maynbridge Capital Inc. (“Maynbridge”).

The corporate restructuring and refinancing is the culmination of over ten
months of efforts to eliminate significant costs and inefficiencies in the
business and transform the Company from one with multiple business lines, in
different industries, operating under a high corporate overhead cost structure,
to a lean and focused company operating one business line under a low-cost
corporate structure. The Company is now solely focused on the rental of quality
assets to top-tier customers in the Western Canadian Sedimentary Basin. The
Company continues to experience strong demand for its rental assets and is now
well positioned to take advantage of the anticipated improvements in rental
rates in conjunction with the overall strengthening of the oil and gas services
market.

Through the restructuring process the Company has significantly reduced its
total debt through the divestures of non-core subsidiaries, the sale of
under-utilized assets and through the retirement of $2.5 million of debt owing
to a company controlled by Mr. Dean Swanberg in exchange for 10 million common
shares (representing a price of $0.25 per share). This conversion will result
in Mr. Swanberg being the largest individual shareholder of the Company, and
the balance of the debt owing to Mr. Swanberg’s company being reduced to $2.5
million. The directors of CERC will be appointing Mr. Swanberg to the Company’s
Board of Directors where his experience and reputation as a veteran oilfield
executive in Western Canada will be of great value to the Company.

As a final step in the restructuring process, the Company will be seeking
shareholder approval at the June 27, 2017 Annual and Special Meeting to change
the name of the Company from Canadian Equipment Rentals Corp. to Zedcor Energy
Inc., thus aligning the parent company branding with its only operating entity,
Zedcor Energy Services Corp.

The Company is pleased to be able to partner with Maynbridge Capital for the
next year through their asset backed lending solution which is well suited for
an asset based rental business such as CERC. In conjunction with this
financing, the directors of CERC will be appointing Mr. Dean Shillington, CEO
of Maynbridge Capital, to the Company’s Board of Directors. Mr. Shillington’s
business and finance expertise will greatly benefit the Company as it executes
on its new sharply focused business plan.

The principal amount of the Maynbridge loan is $20.4 million and it has a term
of one (1) year (plus a day), with an option to extend for an additional year.
The loan bears interest at 12.75% per annum and will be serviced by six months
of interest only payments followed by six months of blended interest and
principal payments. The proceeds from the loan will be used to repay in full
CERC’s existing syndicated credit facility. The loan has no financial covenant
requirements as it is to be secured through the value of the Company’s rental
assets and a $2.5 million guarantee from Mr. Dean Swanberg.

Under the Loan and Security Agreement, the Company will, subject to TSX Venture
Exchange approvals, issue to Maynbridge 3,651,501 share purchase warrants
entitling the holder to acquire that number of common shares in the Company
representing approximately 6.5% of the fully diluted equity of the Company, at
an exercise price of $0.25 per share. The warrants will expire 90 days after
the maturity date of the loan.

The closing of the Maynbridge financing is scheduled for on, or before, April
28th, 2017 and is subject to approval by the TSX Venture Exchange and to the
satisfaction or waiver of certain conditions precedent typical for equipment
loan transactions.

Ernst & Young Orenda Corporate Finance Inc. acted as the Company’s exclusive
financial advisor with respect to the refinancing.

About Canadian Equipment Rentals Corp.

About Maynbridge Capital Inc.

Maynbridge Capital Inc. (www.maynbridge.ca) is a boutique lender that
specializes in equipment and property financing to companies across Canada.
With offices in Vancouver, Calgary, Toronto, Ottawa and Montreal, Maynbridge is
an asset-based lender that assists companies through periods of transition in
all economic climates.

Forward-Looking Statements and Information

Certain statements included or incorporated by reference in this press release
constitute forward-looking statements or forward-looking information.
Forward-looking statements or information may contain statements with the words
“anticipate”, “believe”, “expect”, “plan”, “intend”, “estimate”, “propose”,
“budget”, “should”, “project”, “would have realized’, “may have been” or
similar words suggesting future outcomes or expectations. In particular,
forward-looking statements and information contained in this press release,
include, but are not limited to, the closing of the financing and repayment of
CERC’s existing credit facility by April 28, 2017, the closing of the $2.5
million reduction of debt held by Mr. Swanberg and the appointment of two new
directors. Although the Company believes that the expectations implied in such
forward-looking statements or information are reasonable, undue reliance should
not be placed on these forward-looking statements because the Company can give
no assurance that such statements will prove to be correct. Forward-looking
statements or information are based on current expectations, estimates and
projections that involve a number of assumptions about the future and
uncertainties. Although management believes these assumptions are reasonable,
there can be no assurance that they will be proved to be correct, and actual
results will differ materially from those anticipated. For this purpose, any
statements herein that are not statements of historical fact may be deemed to
be forward-looking statements. The forward-looking statements or information
contained in this press release are made as of the date hereof and the Company
assumes no obligation to update publicly or revise any forward-looking
statements or information, whether as a result of new contrary information,
future events or any other reason, unless it is required by any applicable
securities laws. The forward-looking statements or information contained in
this press release are expressly qualified by this cautionary statement.

– END RELEASE – 24/04/2017

For further information:
Ken Olson
Chief Financial Officer
(403) 930-5434
kolson@cercorp.ca

COMPANY:
FOR: CANADIAN EQUIPMENT RENTALS CORP.
TSX VENTURE SYMBOL: CFL

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170424CC0113

Press Release from Marketwired 1-866-736-3779

Researchers tout more accurate way to measure oilsands air pollutants

April 24, 2017April 24, 2017 by The Canadian Press

CALGARY — Federal government scientists say they have devised an accurate way to directly measure air pollutants from oilsands mines and suggest industry estimates for certain harmful emissions have been much too low.

The research, published Monday in the Proceedings of the National Academy of Sciences, focused on volatile organic compounds, or VOCs — carbon-based substances that can be damaging to the environment and human health.

Oilsands companies have indirect ways of calculating their mines’ estimated VOC emissions. Methods include extrapolating from other substances they measure from smokestacks or from emissions associated with a specific activity, said lead author Shao-Meng Li, a senior research scientist at Environment and Climate Change Canada.

Li and his team set out to compare those figures against direct readings they took from the air above the mines.

Their experiment took measurements from a plane flown at various altitudes in a box-like pattern above oilsands mines in northeastern Alberta. That created a virtual wall of sorts around developments as big as 275 square kilometres.

“Most of these instruments are very bulky, so they cannot be mounted on the outside,” said Li.

The interior of the aircraft looks like a cargo plane with a dozen or so seats for the scientists and racks of gadgets along the wall. Li said the air was brought into containers inside the cabin through special tubing and samples were taken back to the lab for analysis.

The amount of overall VOCs measured on the flights wound up being two to 4 1/2 times higher than figures companies reported to Environment Canada’s National Pollutant Release Inventory.

“It’s quite a powerful mechanism to make those kind of measurements,” said Stewart Cober, co-author of the paper and manager in Environment Canada’s Air Quality Research Division.

“It’s a mechanism we wouldn’t have been able to do 15 years ago because the technology didn’t exist.”

The flights were made in the late summer of 2013. The team is planning another go-round in 2018 to see how the method works in different weather conditions.

Cober said the technique has the potential to be applied to other oil and gas projects, such as hydraulic fracturing sites and in situ oilsands developments, in which steam is used to extract bitumen from deep underground.

“What we’ve done is demonstrated that there is a way to make more accurate measurements,” he said.

Cober hopes the research means emissions can be estimated more accurately in the future, perhaps with industry players doing their own airborne readings.

“It is a game changer,” he said. “Certainly we’re very excited about it.”

Chelsie Klassen of the Canadian Association of Petroleum Producers, wasn’t so sure.

“This study took a snapshot measurement and used that information to determine an hourly emissions profile without consideration of seasonal effects,” said Klassen.

“Further research is needed to make an interpretation of annual emissions to increase accuracy and understand this issue. Industry is actively working to more accurately quantify emissions from surface mining activities.”

Lauren Krugel, The Canadian Press

Inter Pipeline says crude leak east of Edmonton came from its system

April 24, 2017April 24, 2017 by The Canadian Press

EDMONTON — Inter Pipeline Ltd. said Monday that its Cold Lake pipeline was the source of an oil leak discovered late last week in an industrial area east of Edmonton.

The company said it learned of a potential leak near its Strathcona Terminal at around noon Friday, but it wasn’t until Monday morning that it confirmed the oil came from its line.

The Alberta Energy Regulator said several operators had shut in their lines on the right of way when the leak was discovered because the source was unclear.

Inter Pipeline (TSX:IPL) said the leak was contained on Friday and it continues to work on cleaning up the spill as lead responder to the incident.

The Alberta Energy Regulator, which is overseeing the response, said it still doesn’t know how much oil spilled.

AER spokeswoman Monica Hermary said the crude spilled into an unnamed creek that flows into the North Saskatchewan River, but the leak was contained before it reached the river.

The spill killed one bird, while a beaver and a muskrat were taken in for treatment, said Hermary.

Imperial Oil was first to discover the Inter Pipeline leak Friday, and said Sunday that it was responding to a separate leak at its Cold Lake operation.

The company said it estimates about 900,000 litres of produced water spilled from a storage lagoon at its steam-based oilsands operation in northeast Alberta.

Produced water is a byproduct of oil production, with the water pumped to the surface along with the bitumen before being treated and reused in operations.

The Canadian Press

Lonestar West Announces 2016 Year End Financial Results

April 24, 2017 by The Canadian Press

FOR: LONESTAR WEST INC.
TSX VENTURE SYMBOL: LSI

Date issue: April 24, 2017
Time in: 6:32 PM e

Attention:

SYLVAN LAKE, ALBERTA–(Marketwired – April 24, 2017) – Lonestar West Inc. (TSX
VENTURE:LSI) today announced the financial results for the year ended December
31, 2016.

Key points for the year ended December 31, 2016 include:

/T/

— Revenues decreased by 15.2% to $42,641,196 for the year ended December

31, 2016 from $50,304,204 in the prior year comparable period.
— Gross margin(1) was 15.8% for the year ended December 31, 2016, compared
to 20.2% for the prior year comparable period.
— Normalized EBITDAC(2) was $1,191,588 or 2.8% for the year ended December
31, 2016, compared to $4,400,657 or 8.7% for the prior year comparable
period.
— Normalized EBITDAC(3) per basic share decreased to $0.04 for the year
ended December 31, 2016, compared to $0.15 in the prior year comparable
period.
— A contingent loss of $450,000 US was recorded as the result of an Excise
Tax audit.
— Loss before taxes was $7,104,217 for the year ended December 31, 2016,
compared to a loss before taxes of $6,372,370 in the prior year
comparable period.
— Net loss for the year ended December 31, 2016 was $8,350,844, compared
to a net loss of $6,372,370 in the prior year comparable period.

/T/

The Company reported normalized EBITDAC(2) of $1,191,588 for the year ended
December 31, 2016, which is a decrease from $4,400,657 for the prior year
comparable period. The decrease in normalized EBITDAC is due primarily to a
significant decrease in revenue offset by a marginal decrease in operating
expenses. Other factors directly impacted the revenues were a delay in contract
negotiations with a major account in the United States, and the continued
impact of the wildfires in Fort McMurray, Alberta that occurred in the second
quarter of the year.

Key points for the three months ended December 31, 2016 include:

The Company reported negative normalized EBITDAC(2) of $(1,042,388) for the
three month period ended December 31, 2016, which is a decrease from $11,107
for the prior year equivalent period. The decrease in normalized EBITDAC for
the three month period ended December 31, 2016 is related primarily to a lower
gross margin resulting from a more competitive operating environment. In
addition, there were costs associated with the closure and reorganization of
bases that were not performing.

“Results for the fourth quarter were disappointing. Significant cost cutting
was partially completed but the additional selling, general and administration
expenses and the continued decline of the revenue offset the impact of the cuts
we made,” commented James Horvath, President of Lonestar. “We are focused on
working towards our goal of returning the business to its historical operating
and profit margins. This includes continued cost cutting into Q1 of 2017. The
Company has also reduced the number of bases in the US, and we will continue to
direct our business development activities on expanding in our most profitable
locations.”

About Lonestar West

Based in Sylvan Lake, Alberta, Lonestar West Inc. operates a fleet of 140
Hydrovac, Vacuum and Auxiliary units throughout Western Canada, Ontario,
California, and the South Eastern United States. It is focused on profitably
growing its HVAC services to become a major competitor in the North American
market.

For more information please visit the Lonestar West website at
www.lonestarwest.com.

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This News Release contains certain forward-looking statements and
forward-looking information (collectively referred to herein as
“forward-looking statements”) within the meaning of applicable Canadian
securities laws. All statements other than statements of present or historical
fact are forward-looking statements. Forward-looking statements are often, but
not always, identified by the use of words such as “anticipate”, “achieve”,
“could”, “believe”, “plan”, “intend”, “objective”, “continuous”, “ongoing”,
“estimate”, “outlook”, “expect”, “may”, “will”, “project”, “should” or similar
words, including negatives thereof, suggesting future outcomes. In particular,
this News Release contains forward-looking statements relating to: demand for
the Company’s services and general industry activity level; the Company’s
growth opportunities; and expectations regarding the Company’s revenue,
normalized EBITDAC and equipment utilization. Lonestar believes the
expectations reflected in such forward-looking statements are reasonable as of
the date hereof but no assurance can be given that these expectations will
prove to be correct and such forward-looking statements should not be unduly
relied upon.

Various material factors and assumptions are typically applied in drawing
conclusions. Specific material factors and assumptions include, but are not
limited to:

/T/

— Changes in industry conditions (including the levels of capital

expenditures made by oil and gas producers and explorers)
— Credit risk to which the Company is exposed in the conduct of its
business
— Fluctuations in prevailing commodity prices, currency and interest rates
— The competitive environment to which the business is, or may be, exposed
in all aspects of its business
— The ability of the Company to access equipment and new technologies
— The Company’s ability to maintain relationships with key suppliers
— The ability of the Company to attract and maintain key personnel and
other qualified employees
— Various environmental risks to which the Company is exposed in the
conduct of its operations
— Inherent risks associated with the conduct of the business in which the
Company operates
— Timing and costs associated with the acquisition of capital equipment
— The impact of weather and other seasonal factors that affect business
operations
— Availability of financial resources or third-party financing, and;
— The impact of new laws or changes in administrative practices on the
part of regulatory authorities.

/T/

Readers are cautioned that these factors are difficult to predict. Accordingly
readers are cautioned that the actual results achieved will vary from the
information provided herein and the variations may be material. Readers are
also cautioned that the list of factors above are not exhaustive. Before
placing reliance on any forward-looking statements to make decisions with
respect to an investment in securities in Lonestar, prospective investors and
others should carefully consider the factors identified above and other risks,
uncertainties and potential changes that may cause actual results or events to
differ materially from those anticipated in such forward-looking statements.

Forward-looking statements are not a guarantee of future performance and
involve a number of risks and uncertainties, some of which are described
herein. Such forward-looking statements necessarily involve known and unknown
risks and uncertainties, which may cause Lonestar’s actual performance and
financial results in future periods to differ materially from any projections
of future performance or results expressed or implied by such forward-looking
statements. These risks and uncertainties include, but are not limited to, the
risks identified in Lonestar’s annual information form and management
discussion and analysis for the year ended December 31, 2016 (the “MD&A”),
which are available for viewing on SEDAR at www.sedar.com. In addition, the
forward-looking statements contained in this News Release are made as of the
date of this News Release. Lonestar does not undertake any obligation to
publicly update or to revise any forward-looking statements except as expressly
required by applicable securities laws. The forward-looking statements
contained in this Press Release are expressly qualified by the cautionary
statements contained herein.

Notes:

/T/

1. Gross margin is calculated as gross profit as a percentage of revenues
2. This News Release contains the term Normalized EBITDAC as presented and

does not have any standardized meaning prescribed by international
financial reporting standards (“IFRS”) and therefore it may not be
comparable with the calculation of similar measures for other entities.
Management uses normalized EBITDAC to analyze the operating performance
of the business. Normalized EBITDAC as presented is not intended to
represent cash provided by operating activities, net earnings or other
measures of financial performance calculated in accordance with IFRS. It
is defined as Earnings before interest, taxes, depreciation,
amortization, and stock based compensation excluding foreign exchange
gains or losses which are primarily related to the US dollar activities
of the Company and can vary significantly depending on exchange rate
fluctuations, which are beyond the control of the Company.
3. Normalized EBITDAC per share is calculated as Normalized EBITDAC divided
by the weighted average shares outstanding for the period.

/T/

NEITHER THE TSX VENTURE EXCHANGE NOR ITS REGULATION SERVICES PROVIDER (AS THAT
TERM IS DEFINED IN THE POLICIES OF THE TSX VENTURE EXCHANGE) ACCEPTS
RESPONSIBILITY FOR THE ADEQUACY OR ACCURACY OF THIS RELEASE.

– END RELEASE – 24/04/2017

For further information:
Lonestar West Inc.
James Horvath
President & CEO
403-887-2074
info@lonestarwest.com
www.lonestarwest.com

COMPANY:
FOR: LONESTAR WEST INC.
TSX VENTURE SYMBOL: LSI

INDUSTRY: Professional Services – Other Professional Services
RELEASE ID: 20170424CC0111

Press Release from Marketwired 1-866-736-3779

Essential Energy Services 2017 First Quarter Financial Results Conference Call and Webcast Details

April 24, 2017 by The Canadian Press

FOR: ESSENTIAL ENERGY SERVICES LTD.TSX SYMBOL: ESNDate issue: April 24, 2017Time in: 6:05 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 24, 2017) – Essential Energy Services
Ltd. (TSX:ESN) (“Essential”) intends to release its 2017 first quarte…

Wavefront’s Powerwave Technology to Drive Production Enhancement With Middle East Operator

April 24, 2017 by The Canadian Press

FOR: WAVEFRONT TECHNOLOGY SOLUTIONS INC.
TSX VENTURE SYMBOL: WEE
OTCQX SYMBOL: WFTSF

Date issue: April 24, 2017
Time in: 5:21 PM e

Attention:

EDMONTON, ALBERTA–(Marketwired – April 24, 2017) – Wavefront Technology
Solutions Inc. (Wavefront or the Company), (TSX VENTURE:WEE)(OTCQX:WFTSF) an
Oil Field Service (“OFS”) provider focused on enhancing hydrocarbon recovery
through the lifecycle of a production asset is pleased to announce that broader
field deployment of Wavefront’s core fluid injection technology, Powerwave,
will be undertaken in the Sultanate of Oman.

A Powerwave-driven waterflood targets stranded or bypassed oil in a reservoir
which is very difficult to produce due to various physical limitations. Based
on positive results from a limited field trial of Powerwave Wavefront’s
distribution partner in Oman was awarded the approximate US $500,000 contract
for expanded Powerwave use. This previously anticipated Powerwave program was
delayed due to lower and volatile oil prices over the past few years. Powerwave
deployment is in the client’s scheduling phase and is anticipated to commence
in the second half of calendar 2017.

“Wavefront is confident it can replicate or better initial field pilot results
which saw oil production decline rates fall by approximately 4% and overall oil
production rates within the field pilot area improve by up to 47%,” said
Wavefront President and CEO Brett Davidson. “We believe that demonstrating
Powerwave efficacy on a broader scale across varied geological settings will
result in general commercialization of Powerwave with this client.”

ON BEHALF OF THE BOARD OF DIRECTORS

WAVEFRONT TECHNOLOGY SOLUTIONS INC.

D. Brad Paterson, CFO & Director

About Wavefront:

Cautionary Disclaimer – Forward Looking Statement

From Bit To Last Drop(TM), WaveAxe(TM), Powerwave(TM) and Primawave(TM) are
registered trademarks of Wavefront Technology Solutions Inc., or its
subsidiaries, or affiliates.

– END RELEASE – 24/04/2017

For further information:
Wavefront Technology Solutions Inc.
D. Brad Paterson
CFO
780-486-2222
investor.info@onthewavefront.com
www.onthewavefront.com

COMPANY:
FOR: WAVEFRONT TECHNOLOGY SOLUTIONS INC.
TSX VENTURE SYMBOL: WEE
OTCQX SYMBOL: WFTSF

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170424CC0101

Press Release from Marketwired 1-866-736-3779

DXI Calls AGM and Special Shareholders Meeting June 2, 2017

April 24, 2017 by The Canadian Press

FOR: DXI ENERGY INC.
TSX SYMBOL: DXI
OTCQB SYMBOL: DXIEF

Date issue: April 24, 2017
Time in: 5:15 PM e

Attention:

Proposes Financial Restructure to Attract ‘Transformational’ Opportunity

(all figures in Cdn $ unless otherwise indicated)

VANCOUVER, BRITISH COLUMBIA–(Marketwired – April 24, 2017) – DXI Energy Inc.
(TSX:DXI) (OTCQB:DXIEF) (“DXI” or the “Company”), an upstream oil and gas
exploration and production company operating in Colorado’s Piceance Basin and
the Peace River Arch region in British Columbia, tomorrow mails shareholders
details for its AGM and Special Shareholders Meeting to be held June 2, 2017,
already posted on SEDAR.

After extensive deliberation, the independent members of the board of DXI have
approved a series of initiatives to create incremental real value for
stockholders. Subject to shareholder approval, these steps include:

/T/

1. Restructuring equity and debt to provide annual interest savings of

$390K per year:
a. Insiders to equitize $1.3mm of secured debt.
b. Insiders to amend long term obligations by extending the term to 5
years, convertible to shares at $0.077 per share, reshaping the
corporate balance sheet to attract a transformational event.
c. Insiders to cancel 14mm share purchase warrants currently
outstanding.

2. Raising $2.2mm in new equity at $0.06 per share:

a. To eliminate the Company’s working capital deficiency,
b. To support additional exploration at Woodrush, and
c. To provide sufficient working capital to preserve existing assets
and fund costs for a transformational event.

/T/

Upon completion, DXI will emerge well positioned to move forward free of the
financial encumbrances that have limited its endeavours to expand and develop
during the past thirty-month downturn in the commodity markets.

DXI’s current energy portfolio features two highly regarded North American
producing assets. In the Piceance Basin, Colorado, more than US$40mm has been
expended to initiate development of the 2,250 acre Kokopelli Project resulting
in twelve producing wells, including a new 13000′ Mancos gas discovery and the
infrastructure to handle many more. A recent U.S. Geological Survey report
states that the Mancos shale in this Basin contains forty times more natural
gas than previously estimated validating its rank as one of the top two largest
containments of natural gas in the U.S. In NE British Columbia, the 14000+ acre
Woodrush Project, hosts four oil wells and nine gas wells in production since
2009, includes over $13 million in Company-owned production facilities and
pipelines

“As Chairman, the Company’s largest shareholder and its largest debtholder, I
invite all stakeholders to support these strategic initiatives and participate
with us to preserve and enhance our existing investments and create a
productive transformational event,” states Robert L. Hodgkinson, CEO.

WEBSITES WHERE MEETING MATERIALS ARE POSTED: The meeting materials can be
viewed online under the Company’s profile at www.sedar.com (Canada) or at
www.sec.gov (United States). They may also be downloaded from the Company’s
website at www.dxienergy.com/financial-reports.html.

HOW TO OBTAIN PAPER COPIES OF THE MEETING MATERIALS: Beneficial shareholders
may request that a paper copy of the meeting materials be sent to them by
postal delivery at no cost to them. Shareholders may request copies of the
Information Circular at no cost by calling toll-free at 1-866-888-8230.

FORM 20-F FILING: The Company further announces that it has filed its annual
Form 20-F Report (“Form 20-F”) for the year ended December 31, 2016 with the
Securities Exchange Commission on April 21, 2017. The Form 20-F includes the
Company’s annual audited financial statements for the year ended December 31,
2016 as well as the related “Management’s Discussion & Analysis” for the year
then ended. Copies of the Form 20-F can be found on the Company’s website at
“www.dxienergy.com” and on EDGAR. Shareholders wishing to obtain a hard copy of
the complete audited financial statements for the year ended December 31, 2016
free of charge can contact the Company via the email addresses on our website
or by telephone at 604-638-5050.

ABOUT DXI ENERGY INC.:

DXI Energy Inc. is an upstream oil and natural gas exploration and production
company operating projects in Colorado’s Piceance Basin (25,684 net acres) and
the Peace River Arch region in British Columbia (14,444 net acres). DXI Energy
Inc. maintains offices in Calgary and Vancouver, Canada. The company is
publicly traded on the Toronto Stock Exchange (DXI.TO) and the OTCQB (DXIEF).

Statements Regarding Forward-Looking Information: This news release contains
statements about oil and gas production and operating activities that may
constitute “forward-looking statements” or “forward-looking information” within
the meaning of applicable securities legislation as they involve the implied
assessment that the resources described can be profitably produced in the
future, based on certain estimates and assumptions. Forward-looking statements
are based on current expectations, estimates and projections that involve a
number of risks, uncertainties and other factors that could cause actual
results to differ materially from those anticipated by DXI Energy and described
in the forward-looking statements. These risks, uncertainties and other factors
include, but are not limited to, adverse general economic conditions, operating
hazards, drilling risks, inherent uncertainties in interpreting engineering and
geologic data, competition, reduced availability of drilling and other well
services, fluctuations in oil and gas prices and prices for drilling and other
well services, government regulation and foreign political risks, fluctuations
in the exchange rate between Canadian and US dollars and other currencies, as
well as other risks commonly associated with the exploration and development of
oil and gas properties. Additional information on these and other factors,
which could affect DXI Energy Inc.’s operations or financial results, are
included in DXI Energy Inc.’s reports on file with Canadian and United States
securities regulatory authorities. We assume no obligation to update
forward-looking statements should circumstances or management’s estimates or
opinions change unless otherwise required under securities law.

The TSX does not accept responsibility for the adequacy or accuracy of this
news release.

Follow DXI Energy’s latest developments on: Facebook
http://facebook.com/dxienergy and Twitter @dxienergy.

– END RELEASE – 24/04/2017

For further information:
Robert L. Hodgkinson
Chairman & CEO
604-638-5055
investor@dxienergy.com
OR
David Matheson
CFO
604-638-5054
dmatheson@dxienergy.com
OR
Craig Allison
Investor Relations- New York
914-882-0960
callison@dxienergy.com

COMPANY:
FOR: DXI ENERGY INC.
TSX SYMBOL: DXI
OTCQB SYMBOL: DXIEF

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170424CC0100

Press Release from Marketwired 1-866-736-3779

Savanna Announces Change of Control Offer for Outstanding Senior Notes and Temporary Waiver from Syndicated Credit Facility Lenders

April 24, 2017 by The Canadian Press

FOR: SAVANNA ENERGY SERVICES CORP.
TSX SYMBOL: SVY

Date issue: April 24, 2017
Time in: 4:51 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 24, 2017) – Savanna Energy Services
Corp. (“Savanna”) (TSX:SVY) announces that, in connection with the acquisition
by Total Energy Services Inc. (“Total”) of more than 50% of the outstanding
common shares of Savanna pursuant to Total’s offer to purchase all of the
common shares of Savanna (the “Change of Control”), Savanna has issued a Notice
of Change of Control and Change of Control Offer (the “Offer”) to repurchase
the outstanding Cdn. $107.085 million aggregate principal amount of 7.00%
senior unsecured notes of Savanna due 2018 (the “Notes”) at a price equal to
101% of the aggregate principal amount of the Notes repurchased, plus accrued
and unpaid interest on such Notes up to, but excluding, the date of purchase.

The Offer is open for acceptance by the holders of the Notes until 4:00 p.m.
(Calgary time) on Thursday, June 22, 2017.

Savanna has entered into an agreement with Phillips, Hager & North Investment
Management (“PH&N”), which holds Cdn. $60 million aggregate principal amount of
Notes, whereby PH&N has agreed that it will not tender its Notes to the Offer.

Should a holder of Notes elect not to tender its Notes to the Offer, such Notes
will remain outstanding as obligations of Savanna and will mature as originally
set out in the indenture governing such Notes.

The Board of Directors of Savanna has not made any recommendations with respect
to whether holders of the Notes should tender their Notes under the Offer. Each
holder must decide whether to tender their Notes under the Offer. Holders are
urged to evaluate carefully all information regarding the Notes at
www.sedar.com and to consult their own investment, legal, tax and other
professional advisors and to make their own decision whether to tender their
Notes.

Savanna is continuing to review its refinancing options, specifically through
engagement with Total with respect to all possible options, and expects that
any such refinancing required for the repurchase of any Notes tendered to the
Offer prior to expiry of the Offer will be available to Savanna.

Savanna also announces it has entered into a temporary waiver agreement (the
“Waiver”) with the lenders of its syndicated credit facilities (the “Credit
Facilities”). Pursuant to the Waiver, such lenders have: (a) acknowledged
certain defaults under the Credit Facilities that have occurred as a result of
the Change of Control and the previously announced demand for payment pursuant
to Savanna’s second lien credit facility; and (b) waived such defaults until
the earliest to occur of: (i) 2 business days immediately preceding the date of
any repayment or redemption of the Notes, (ii) the occurrence of any other
default or event of default under the Credit Facilities or other credit
document, and (iii) May 15, 2017.

About Savanna

Savanna is a leading contract drilling and oilfield services company operating
in North America and Australia providing a broad range of drilling, well
servicing and related services with a focus on fit for purpose technologies and
industry-leading Aboriginal relationships.

Cautionary Statements

This press release contains forward-looking statements and forward-looking
information within the meaning of applicable securities laws. The use of any of
the words “expect”, “anticipate”, “continue”, “estimate”, “may”, “will”,
“project”, “should”, “believe”, “plans”, “intends” and similar expressions are
intended to identify forward-looking information or statements. More
particularly and without limitation, this press release contains
forward-looking statements and information relating to the Offer, the expiry
date of the Offer, the expectations with respect to PH&N not tendering its
Notes to the Offer and the expected financing for the repurchase of any Notes
tendered to the Offer. These forward-looking statements and information are
based on certain key expectations and assumptions made by Savanna. Assumptions
have been made with respect to the ability of Savanna to finance the repurchase
of the Notes tendered to the Offer and that PH&N will not tender its Notes to
the Offer. Although Savanna believes that the expectations and assumptions on
which such forward-looking statements and information are based are reasonable,
undue reliance should not be placed on the forward-looking statements and
information as Savanna cannot give any assurance that they will prove to be
correct. Since forward-looking statements and information address future events
and conditions, by their very nature they involve inherent risks and
uncertainties. Actual results could differ materially from those currently
anticipated due to a number of factors and risks. These include, but are not
limited to, the failure to obtain the necessary financing for amounts required
to repurchase Notes tendered to the Offer on terms satisfactory to Savanna or
at all.

Readers are cautioned that the foregoing list of risks and uncertainties is not
exhaustive. Other risk factors that could affect Savanna’s operations or
financial results are included in Savanna’s annual information form and may be
accessed through the SEDAR website (www.sedar.com). The forward-looking
statements and information contained in this press release are made as of the
date hereof and Savanna does not undertake any obligation to update publicly or
revise any forward-looking statements or information, whether as a result of
new information, future events or otherwise, unless so required by applicable
securities laws.

– END RELEASE – 24/04/2017

For further information:
Savanna Energy Services Corp.
Daniel Halyk
President and Chief Executive Officer
OR
Savanna Energy Services Corp.
Rick Torriero
Vice-President, Finance
(403) 503-9990

COMPANY:
FOR: SAVANNA ENERGY SERVICES CORP.
TSX SYMBOL: SVY

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170424CC0095

Press Release from Marketwired 1-866-736-3779

PrairieSky Announces First Quarter 2017 Results

April 24, 2017 by The Canadian Press

FOR: PRAIRIESKY ROYALTY LTD.
TSX SYMBOL: PSK

Date issue: April 24, 2017
Time in: 4:01 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 24, 2017) – PrairieSky Royalty Ltd.
(“PrairieSky” or the “Company”) (TSX:PSK) is pleased to announce its first
quarter operating and financial results for the period ended March 31, 2017.

2017 First Quarter Highlights:

/T/

— Average royalty production of 26,812 BOE per day, 49% liquids

— Funds from operations of $67.3 million or $0.28 per share, basic and

diluted

— Revenues of $80.3 million including $73.5 million of royalty revenue

— Leased land for new and existing plays, collecting $3.0 million in lease

issuance bonus consideration

— Completed acquisition of 4% gross overriding royalty on current and

future phases of the Lindbergh SAGD thermal oil project

— Maintained a strong balance sheet with $97.6 million of positive working

capital, including $92.4 million of cash on hand and nil debt as of
March 31, 2017

/T/

PRESIDENT’S MESSAGE

It was an active first quarter for industry and across PrairieSky’s land base
with over 185 wells spud on our lands. Drilling activity was primarily focused
on the Viking light oil play in Western Saskatchewan, the multi-zone Deep Basin
fairway of Alberta and British Columbia and light oil plays across Central
Alberta including the Mannville and Viking plays. Leasing interest remained
high during the quarter with PrairieSky entering into 36 new leasing
arrangements with 33 different producers on our fee lands.

PrairieSky completed its previously announced acquisition of a 4% gross
overriding royalty on current and future phases of Pengrowth Energy
Corporation’s Lindbergh SAGD thermal oil project as well as seismic over
certain lands in British Columbia and Alberta for total cash consideration of
$250 million, before customary closing adjustments. In addition, PrairieSky
completed $4.6 million of complementary acquisitions during the quarter, adding
additional fee title lands and gross overriding royalty interests to its
portfolio, including an overriding royalty on 29,440 acres of land in the
Monias area of Northeast British Columbia which is prospective for future
Montney development. PrairieSky continues to be selective and disciplined in
our evaluation of new royalty opportunities.

PrairieSky’s large undeveloped land position, low cost structure and high
margin royalty production continues to deliver strong funds flow and growth
opportunities with no capital requirements. During the quarter, PrairieSky
declared dividends of $43.2 million. PrairieSky increased its annual dividend
to $0.75 per share per annum effective for the March 2017 dividend which was
paid on April 17, 2017. PrairieSky acquired and cancelled 335,200 common shares
for $10.1 million under its normal course issuer bid (“NCIB”) during the first
quarter of 2017. In addition to paying the dividend and cancelling shares
through the NCIB, PrairieSky continued to add internally generated cash to its
balance sheet. At March 31, 2017, PrairieSky had $97.6 million of positive
working capital and no debt.

PrairieSky will apply to the Toronto Stock Exchange (“TSX”) to renew its NCIB
for an additional one year period. Subject to regulatory approval, PrairieSky
currently intends to allocate up to $44 million over the next 12 months
(approximately $3.7 million per month), net of regular monthly dividend
payments, to repurchase common shares. PrairieSky intends to purchase from time
to time, as it considers advisable, up to 1,600,000 of its currently issued and
outstanding common shares (representing approximately 1% of the public float of
common shares issued and outstanding as of April 24, 2017) over a period of
twelve months. Any common shares that are purchased under the NCIB will be
cancelled upon their purchase by PrairieSky. Management believes a normal
course issuer bid provides an opportunity to use excess cash resources to
reduce PrairieSky’s share count over time, representing an investment in
PrairieSky’s high quality asset base and enhancing value for remaining
shareholders. To date, PrairieSky has purchased and cancelled an aggregate of
1,356,700 common shares at a weighted average price per share of $27.91 under a
normal course issuer bid that commenced on May 2, 2016 and runs to May 1, 2017.

PrairieSky is pleased to be hosting an investor day on May 24, 2017 in Toronto,
Ontario, where members of PrairieSky’s management and technical team will
present details on the Company’s oil and gas plays.

I would like to thank our shareholders for their continued support. Please
contact Pam Kazeil, our Chief Financial Officer, at 587-293-4089 or myself at
587-293-4005 with any questions.

Andrew Phillips

President & CEO

FINANCIAL AND OPERATIONAL INFORMATION

The following table summarizes select operational and financial information of
the Company for the periods noted. All dollar amounts are stated in Canadian
dollars unless otherwise noted.

/T/

FINANCIAL RESULTS

Three months Three months
($ Millions, except per share or as otherwise ended March ended March
noted) 31, 2017 31, 2016
———————————————— ————- ————-
FINANCIAL
Revenues $ 80.3 $ 48.9
Funds from Operations 67.3 41.4
Per Share – basic and diluted (1)(4) 0.28 0.18
Net Earnings and Comprehensive Income 20.8 1.7
Per Share – basic and diluted(1) 0.09 0.01
Dividends declared(2) 43.2 63.3
Per Share 0.1825 0.2767
Acquisitions including non-cash consideration 254.5 2.7
Working Capital at end of period 97.6 202.5
Shares Outstanding 237.0 229.0
Weighted average – basic 236.5 228.6
Weighted average – diluted 236.9 228.8
OPERATIONAL
Production Volumes
Natural Gas (MMcf/d) 81.6 70.7
Crude Oil (bbls/d) 10,214 8,748
NGL (bbls/d) 2,998 2,550
———————————————— ————- ————-
Total (BOE/d)(3) 26,812 23,081
———————————————— ————- ————-
Realized Pricing
Natural Gas ($/Mcf) $ 2.26 $ 1.80
Crude Oil ($/bbl) 52.81 34.16
NGL ($/bbl) 30.94 19.09
———————————————— ————- ————-
Total ($/BOE)(3) $ 30.45 $ 20.56
———————————————— ————- ————-

Operating Netback per BOE(4) $ 27.14 $ 15.66
Funds from Operations per BOE $ 27.89 $ 19.71
Natural Gas Price Benchmarks
AECO ($/Mcf) 2.94 2.11
Oil Price Benchmarks
West Texas Intermediate (WTI) (US$/bbl) 51.79 32.34
Edmonton Light Sweet ($/bbl) 64.29 42.18
—————————————————————————-
—————————————————————————-
(1) Net Earnings and Comprehensive Income and Funds from Operations per
common share are calculated using the weighted average number of common
shares outstanding.
(2) A dividend of $0.0625 per common share was declared on March 9, 2017 and
paid on April 17, 2017 to shareholders of record as at March 31, 2017.
(3) See “Conversions of Natural Gas to BOE”.
(4) A Non-GAAP measure which is defined under the Non-GAAP Measures section
in PrairieSky’s MD&A.

/T/

A full version of PrairieSky’s Management’s Discussion and Analysis (“MD&A”)
and unaudited interim condensed financial statements and notes thereto for the
fiscal period ended March 31, 2017 is available on SEDAR at www.sedar.com and
PrairieSky’s website at www.prairiesky.com.

NORMAL COURSE ISSUER BID

PrairieSky will apply to extend its NCIB for an additional one year period.
Under the renewed NCIB, and subject to prior approval of the TSX, PrairieSky
intends to repurchase up to $44 million of common shares (approximately $3.7
million per month) over a 12 month period. The NCIB has been approved by the
Company’s board of directors; however, it is subject to acceptance by the TSX
and, if accepted, will be made in accordance with the applicable rules and
policies of the TSX and applicable securities laws. Under the NCIB, common
shares may be repurchased in open market transactions on the TSX, and/or other
Canadian exchanges, or by such other means as may be permitted by the TSX and
applicable securities laws. The price that PrairieSky will pay for common
shares in open market transactions will be the market price at the time of
purchase. Common shares acquired under the NCIB will be cancelled.

PrairieSky will file a Notice of Intention to Make a NCIB to purchase and
cancel up to 1,600,000 currently issued and outstanding common shares,
representing approximately 1% of the public float of common shares issued and
outstanding as of April 24, 2017. The NCIB is expected to commence shortly
after regulatory approvals are obtained. Common shares may be repurchased under
the program over a period of up to one year. To date, PrairieSky has purchased
and cancelled an aggregate of 1,356,700 common shares at a weighted average
price per share of $27.91 under a normal course issuer bid that commenced on
May 2, 2016 and runs to May 1, 2017.

PrairieSky will be entering into an automatic purchase plan with its broker in
order to facilitate purchases of its common shares. The automatic purchase plan
allows for purchases by the Company of its common share at any time, including,
without limitation, when the Company would ordinarily not be permitted to make
purchases due to regulatory restriction or self-imposed blackout periods.
Purchases will be made by PrairieSky’s broker based upon the parameters
prescribed by the TSX and the terms of the parties’ written agreement.

PrairieSky believes renewing the NCIB as part of its capital management
strategy is in the best interests of the Company and represents an attractive
opportunity to use cash resources, net of regular dividend payments, to reduce
PrairieSky’s share count over time and thereby enhance the value of the shares
held by remaining shareholders. The Board currently intends to evaluate the
NCIB, and the level of purchases thereunder, on an annual basis in conjunction
with PrairieSky’s annual dividend review. The next regularly scheduled dividend
review will be in February 2018.

While PrairieSky currently intends to only use $44 million to effect NCIB
purchases over the next 12 months, the Company’s board of directors may
consider, from time to time, applying to the TSX to increase the amount of NCIB
purchases. Decisions regarding increases to the NCIB will be based on market
conditions, share price, best use of funds from operations, and other factors
including other options to expand our portfolio of royalty assets.

INVESTOR DAY

PrairieSky will be hosting an investor day on May 24, 2017 in Toronto, Ontario,
where members of PrairieSky’s management and technical team will present
details on the Company’s oil and gas plays. The investor day will be live
webcast starting at 9:00 AM eastern daylight time. Interested parties may
participate in the webcast available through PrairieSky’s investor center at
www.prairiesky.com. A copy of materials will also be available on PrairieSky’s
website at www.prairiesky.com. The webcast will be archived and accessible for
replay after the event.

CONFERENCE CALL DETAILS

A conference call to discuss the results will be held for the investment
community on Tuesday, April 25, 2017 beginning at 6:30 a.m. MDT (8:30 a.m.
EDT). To participate in the conference call, approximately 10 minutes prior to
the conference call, please dial:

(866) 413-7174 (toll free in North America)

(647) 427-2293 (International)

FORWARD-LOOKING STATEMENTS

This press release includes certain statements regarding PrairieSky’s future
plans and operations and contains forward-looking statements that we believe
allow readers to better understand our business and prospects. The use of any
of the words “expect”, “anticipate”, “continue”, “estimate”, “objective”,
“ongoing”, “may”, “will”, “project”, “should”, “believe”, “plans”, “intends”,
“strategy” and similar expressions are intended to identify forward-looking
information or statements. Forward-looking statements contained in this press
release include our expectations with respect to PrairieSky’s business and
growth strategy, additional land leasing activities, renewal of the NCIB and
application to the TSX in respect of the same, the potential to increase the
size of the NCIB in the future, the dollar amount and number of common shares
which may be purchased under the NCIB, and PrairieSky’s belief that
repurchasing such common shares under the NCIB is a good investment of
PrairieSky’s cash resources.

With respect to forward-looking statements contained in this press release, we
have made several assumptions including those described in detail in our MD&A
and the Annual Information Form for the year ended December 31, 2016. Readers
and investors are cautioned that the assumptions used in the preparation of
such forward-looking information and statements, although considered reasonable
at the time of preparation, may prove to be imprecise and, as such, undue
reliance should not be placed on forward-looking statements. Our actual
results, performance, or achievements could differ materially from those
expressed in, or implied by, these forward-looking statements. We can give no
assurance that any of the events anticipated will transpire or occur, or if any
of them do, what benefits we will derive from them.

By their nature, forward-looking statements are subject to numerous risks and
uncertainties, some of which are beyond our control, including the impact of
general economic conditions, industry conditions, volatility of commodity
prices, lack of pipeline capacity, currency fluctuations, imprecision of
reserve estimates, royalties, environmental risks, taxation, regulation,
changes in tax or other legislation, competition from other industry
participants, the lack of availability of qualified personnel or management,
stock market volatility, political and geopolitical instability and our ability
to access sufficient capital from internal and external sources. In addition,
PrairieSky is subject to numerous risks and uncertainties in relation to
acquisitions. These risks and uncertainties include risks relating to the
potential for disputes to arise with counterparties, and limited ability to
recover indemnification under certain agreements. The foregoing and other risks
are described in more detail in PrairieSky’s MD&A, and the Annual Information
Form for the year ended December 31, 2016 under the headings “Risk Management”
and “Risk Factors”, respectively, each of which is available at www.sedar.com.

Further, any forward-looking statement is made only as of the date of this
press release, and PrairieSky undertakes no obligation to update or revise any
forward-looking statement or statements to reflect events or circumstances
after the date on which such statement is made or to reflect the occurrence of
unanticipated events, except as required by applicable securities laws. New
factors emerge from time to time, and it is not possible for PrairieSky to
predict all of these factors or to assess in advance the impact of each such
factor on PrairieSky’s business or the extent to which any factor, or
combination of factors, may cause actual results to differ materially from
those contained in any forward-looking statements.

The forward-looking information contained in this document is expressly
qualified by this cautionary statement.

CONVERSIONS OF NATURAL GAS TO BOE

To provide a single unit of production for analytical purposes, natural gas
production and reserves volumes are converted mathematically to equivalent
barrels of oil (BOE). PrairieSky uses the industry-accepted standard conversion
of six thousand cubic feet of natural gas to one barrel of oil (6 Mcf = 1 bbl).
The 6:1 BOE ratio is based on an energy equivalency conversion method primarily
applicable at the burner tip. It does not represent a value equivalency at the
wellhead and is not based on either energy content or current prices. While the
BOE ratio is useful for comparative measures and observing trends, it does not
accurately reflect individual product values and might be misleading,
particularly if used in isolation. As well, given that the value ratio, based
on the current price of crude oil to natural gas, is significantly different
from the 6:1 energy equivalency ratio, using a 6:1 conversion ratio may be
misleading as an indication of value.

NON-GAAP MEASURES

Certain measures in this document and PrairieSky’s MD&A do not have any
standardized meaning as prescribed by International Financial Reporting
Standards (“IFRS”) and, therefore, are considered non-GAAP measures. Non-GAAP
measures are commonly used in the oil and gas industry and by PrairieSky to
provide potential investors with additional information regarding the Company’s
liquidity and its ability to generate funds to conduct its business. Further
information can be found in the Non-GAAP Measures section of PrairieSky’s MD&A.

ABOUT PRAIRIESKY ROYALTY LTD.

PrairieSky is a royalty-focused company, generating royalty revenues as
petroleum and natural gas are produced from its properties. PrairieSky has a
diverse portfolio of properties that have a long history of generating free
cash flow and that represent the largest and most concentrated
independently-owned fee simple mineral title position in Canada. PrairieSky’s
common shares trade on the Toronto Stock Exchange under the symbol PSK.

– END RELEASE – 24/04/2017

For further information:
PrairieSky Royalty Ltd.
Andrew Phillips
President & Chief Executive Officer
587-293-4005
OR
PrairieSky Royalty Ltd.
Pamela Kazeil
Vice President, Finance & Chief Financial Officer
587-293-4089
OR
PrairieSky Royalty Ltd.
Investor Relations
(587) 293-4000
www.prairiesky.com

COMPANY:
FOR: PRAIRIESKY ROYALTY LTD.
TSX SYMBOL: PSK

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170424CC0089

Press Release from Marketwired 1-866-736-3779

Nesscap Energy Inc. Announces Shareholders Approval of Plan of Arrangement with Maxwell Technologies Inc.

April 24, 2017 by The Canadian Press

FOR: NESSCAP ENERGY INC.TSX VENTURE SYMBOL: NCEDate issue: April 24, 2017Time in: 3:43 PM eAttention:
TORONTO, ONTARIO–(Marketwired – April 24, 2017) – Nesscap Energy Inc. (the
“Company” or “Nesscap”) (TSX VENTURE:NCE), announces that at a special mee…

Alex Blyumkin Announces Acquisition of Common Shares of MCW Energy Group Limited in a Private Placement

April 24, 2017April 24, 2017 by The Canadian Press

FOR: ALEX BLYUMKIN
Date issue: April 24, 2017Time in: 3:15 PM eAttention:
LOS ANGELES, CALIFORNIA–(Marketwired – April 24, 2017) – Alex Blyumkin (“Mr.
Blyumkin”), Executive Chairman and a director of MCW Energy Group Limited (the
“Corporation”), has f…

Notley says Canada will have lots of allies if Trump goes after energy trade

April 24, 2017April 24, 2017 by The Canadian Press

GUANGZHOU, China — Alberta Premier Rachel Notley says U.S. President Donald Trump is likely to have some unhappy supporters south of the border if he goes after Canadian energy with trade sanctions.

Notley, who is on a trade mission in China, says she doesn’t know what Trump was talking about last week when he lumped energy in with what he considers are other trade irritants, including softwood lumber and dairy.

“We’re not exactly sure what it is he was referring to,” Notley said in a conference call Monday. “We’re trying to get a sense of that.”

She noted that many of Trump’s backers need and want energy from north of the border, so Canada is likely to have a lot of allies.

“The leadership of the U.S. administration is going to find that they have a lot of their own stakeholders reminding them how much they need Canadian energy,” she said.

“It’s not something as simple as just throwing a border adjustment tax, because in fact there will be huge consequences and cost increases for a number of different players throughout the U.S. should that happen.”

Canada has found itself in the crosshairs as Trump pushes for what he says will be “very big changes” to the North American Free Trade Agreement.

Trump has upped his rhetoric on NAFTA and is calling the deal a disaster that he plans to get rid of once and for all.

Notley said Trump’s talk is another argument for expanding the Trans Mountain pipeline to the B.C. coast so Alberta’s oil can be shipped to other markets overseas.

The Canadian Press

Statoil Receives Common Shares of International Petroleum Corporation From Lundin Petroleum

April 24, 2017 by The Canadian Press

FOR: STATOIL ASAOSLO SYMBOL: STLDate issue: April 24, 2017Time in: 2:58 PM eAttention:
STAVANGER, NORWAY–(Marketwired – April 24, 2017) – Statoil ASA (OSLO:STL)
(“Statoil”) announced today that it beneficially owns 22,805,892 Common Shares
(“Shares”) …

Energy Navigator to Present Full-day Courses in Type Well Construction: May 15th Calgary, AB (FREE), May 19th The Woodlands, TX: See Details HERE

June 28, 2017April 24, 2017 by EnergyNow Media

SPE Distinguished lecturers Lee, Freeborn, and Sidle to teach course in Calgary and The Woodlands Calgary, AB, Canada, April 24, 2017 – Each year, companies use typical well production profiles (type wells) to support billion-dollar expenditures to buy and develop oil and gas resources. Unfortunately, these type wells can often have unrepresentative rate-time profiles and recoveries … Read more

Weekly Canadian Oil & Gas Industry Highlights – April 24, 2017

June 28, 2017April 24, 2017 by EnergyNow Media

April 24, 2017 Presented by POIM Consulting Group Major /Interesting Projects Catapult Environmental Inc. large water injection facility FOX CREEK 07-07-062-18W5 Birchcliff Energy Ltd. Large Oil Satellite POUCE COUPE SOUTH 03-15-078-11W6 Murphy Oil Company Ltd. Large Gas Battery SIMONETTE 01-12-064-25W5 Storm Resources Ltd 6 well license Beatton River BC Teine Energy Ltd 21 Well License … Read more

Precision Drilling reports higher rig demand but lower pricing in Q1; loss rises

April 24, 2017 by The Canadian Press

CALGARY — One of Canada’s largest oil and gas drilling companies is seeing renewed demand for its services but at lower prices.

Calgary-based Precision Drilling (TSX:PD) says it activated 17 rigs in its U.S. fleet, bringing the total to 56.

Precision Drilling also had 91 active rigs in Canada at the end of the quarter, up from 50 at the beginning of the year.

Revenue for the three months ended March 31 was up 14.6 per cent from last year, but Precision Drilling’s net loss also increased due to higher operating expenses and lower pricing for all its North American businesses.

Net loss was $22.6 million or eight cents per share, compared with $19.9 million or seven cents per share a year earlier. Operating loss was $12.9 million, compared with a year-earlier operating profit of $4 million.

Precision Drilling had $345.8 million of revenue, up 14.6 per cent from the first quarter of 2016. Cash provided by operations fell, however, to $33.8 million from $112.2 million.

The Canadian Press

New West Energy Services Inc. Provides Corporate Update and Announces Share Consolidation

April 24, 2017 by The Canadian Press

FOR: NEW WEST ENERGY SERVICES INC.TSX VENTURE SYMBOL: NWEDate issue: April 24, 2017Time in: 8:30 AM eAttention:
New West completes strong winter season and expects significantly higher
revenues in the upcoming summer season compared to last year
CALGAR…

Primeline CFO to Step Down

April 24, 2017 by The Canadian Press

FOR: PRIMELINE ENERGY HOLDINGS INC.TSX VENTURE SYMBOL: PEHDate issue: April 24, 2017Time in: 7:56 AM eAttention:
HONG KONG, CHINA–(Marketwired – April 24, 2017) –
Not for distribution to U.S. news wire services, or dissemination in the United
States.
…

Greenfields Petroleum Corporation Announces the Signing of a Protocol on the Carry of SOA, an Amended Gas Sales Agreement, 2016 Year-End Reserves and 2017 Budget

April 24, 2017 by The Canadian Press

FOR: GREENFIELDS PETROLEUM CORPORATION
TSX VENTURE SYMBOL: GNF

Date issue: April 24, 2017
Time in: 7:30 AM e

Attention:

HOUSTON, TEXAS–(Marketwired – April 24, 2017) – Greenfields Petroleum
Corporation (“Greenfields” or the “Company”)(TSX VENTURE:GNF) announces that
Bahar Energy Limited (“BEL”), a wholly owned subsidiary of the Company, has
signed a protocol in respect of the carry of certain costs and related issues
(the “Protocol”), and that Bahar Energy Operating Company Limited (“BEOC”), the
operating company for BEL, has signed an amendment to the gas sales agreement
(the “Amended GSA”) for the sale of non-associated natural gas produced under
the Exploration, Rehabilitation, Development and Production Sharing Agreement
(the “ERDPSA”) with the State Oil Company of Azerbaijan (“SOCAR”) and SOCAR Oil
Affiliate (“SOA”) in Azerbaijan.

The Protocol between BEL and SOCAR addresses the shortfall by SOA in its
funding of its 20% share of project expenditures incurred under the ERDPSA
since April 2014. As of March 31, 2017, this funding shortfall and the Carry 1
amounts owed to BEL pursuant to the ERDPSA totalled approximately $40 million.
As provided in the ERDPSA, these amounts will be repaid to BEL from SOA’s share
of cost recovery. In addition, from April 19, 2017 (being the effective date of
the Protocol), all funds generated by the sale of petroleum produced from the
contract rehabilitation area which are allocated to SOA for profit petroleum
and to SOCAR as compensatory petroleum (the “Protocol Funds”) will now be
placed in a separate fund. The Protocol Funds will be used to fund SOA’s
monthly cash call obligation. In the event the Protocol Funds are insufficient
to cover the payment of SOA’s cash calls, BEL will fund such shortfall. Any
funding by BEL of the deficiencies in SOA’s cash call payments will be added to
the outstanding Carry 1 balance and subsequently reimbursed in accordance with
the terms of the ERDPSA through payment of SOA’s share of cost recovery
revenues to BEL. The Protocol has a three-year term.

On October 1, 2015, the original gas sales agreement (the “Original GSA”) for
the sale of non-associated natural gas from the Bahar Gas Field expired.
Natural gas sales from the Bahar Gas Field continued on a month to month basis
on the original terms set forth in the Original GSA while a revised gas sales
agreement was negotiated with SOCAR. With the continued difficult economic
conditions in Azerbaijan due to low oil prices, SOCAR has placed pressure on
all production sharing agreement holders to lower prices for natural gas sold
to SOCAR for domestic consumption. As a result, on March 3, 2017, BEOC signed
the Amended GSA, which extends the term of the arrangement by 5 years and
establishes a fixed natural gas price of $95/mcm ($2.69/mcf), which is reduced
from the natural gas price of $140/mcm ($3.96/mcf) established by the Original
GSA. In addition, the Amended GSA expands SOCAR’s obligation to purchase
non-associated natural gas. Under the terms of the Original GSA, SOCAR
purchased only non-associated natural gas from Bahar Gas Field. Under the terms
of the Amended GSA, SOCAR will also purchase non-associated natural gas from
all natural gas zones in the Gum Deniz Oil Field and/or any new gas discoveries
in the contract area.

Year-End Reserves

The Company is pleased to announce the Company’s oil, natural gas and natural
gas liquids (“NGL”) reserves as at December 31, 2016, as evaluated by an
independent engineering firm, GLJ Petroleum Consultants Ltd. (“GLJ”) in an
independent report (the “GLJ Report”). The following figures were prepared in
accordance with the standards contained in the Canadian Oil and Gas Evaluation
Handbook (the “COGE Handbook”) and the reserve definitions contained in
National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities
(“NI 51-101”). See “Information Regarding Disclosure on Oil and Gas Reserves”
in this press release.

As at December 31, 2016, the total proved reserves of the Company were
evaluated at 24,409 MBOE net to the Company through its interest in BEL, which
is an increase of 236% over year-end 2015, and the total proved plus probable
reserves were evaluated at 40,016 MBOE net to the Company, an increase of 220%
over year-end 2015. In August 2016, the Company acquired the remaining
two-thirds interest in BEL which holds an 80 percent working interest in the
Bahar ERDPSA. With 100% ownership of BEL, this resulted in net present value of
proved reserves discounted at 10% (“PV10”) of $138.5 million net to the Company
at year-end 2016 (an increase of 193% from year-end 2015), while the PV10 of
the proved plus probable reserves is $318.4 million at year-end 2016 (an
increase of 204% from year-end 2015).

/T/

— The net present value of proved plus probable reserves for BEL’s 100%

interest, discounted at 10%, increased a nominal 1% to $318.4 million at
December 31, 2016 from $314.2 million at year-end 2015 despite a 32
percent decrease in the natural gas commodity price under the Amended
GSA.

— Project value was retained as a result of substantial cost saving

measures that were undertaken by BEOC to reduce the project operating
costs, the costs of executing both oil and gas workovers and the costs
of platform refurbishment which more than offset the impact of commodity
price reductions.

/T/

The Company’s reserves at December 31, 2016 as set forth in the GLJ Report are
summarized below:

/T/

—————————————————————————-

2015 Total
2015 Total 2016 Total Proved +
Greenfields Proved (1P) Proved (1P) Probable (2P)
Net Reserves (1) MBOE MBOE MBOE
—————————————————————————-
Light & Medium Crude Oil and
NGL 2,071 6,275 3,816
—————————————————————————-
Conventional Natural Gas 5,203 18,134 8,683
—————————————————————————-
TOTAL 7,274 24,409 12,499
—————————————————————————-
NPV 10%(in thousands) $47,226 $138,495 $104,741
—————————————————————————-

—————————————————————————-

2015 Total 2016 Total
2016 Total Proved + Proved +
Proved + Probable + Probable +
Greenfields Probable (2P) Possible (3P) Possible(3P)
Net Reserves (1) MBOE MBOE MBOE
—————————————————————————-
Light & Medium Crude Oil and
NGL 11,952 5,343 16,455
—————————————————————————-
Conventional Natural Gas 28,064 11,225 37,203
—————————————————————————-
TOTAL 40,016 16,567 53,658
—————————————————————————-
NPV 10%(in thousands) $318,352 $165,396 $469,431
—————————————————————————-
Note:
(1) Reserves disclosure for year-end 2015 reflects Greenfields’ 33.33% share
interest in BEL, whereas the year-end 2016 reserves data reflects
Greenfields’ interest after giving effect to the acquisition on August
9, 2016 of the remaining two-thirds share interest in BEL.

/T/

GLJ estimates the future development costs (“FDC”) required to convert
undeveloped and non-producing reserves to producing reserves at $249 million.
This includes the drilling of 18 proved and 17 probable undeveloped locations
in the Gum Deniz Oil Field and recompletion of 38 gas wells in the Bahar Gas
Field. The GLJ Report anticipates these wells to be drilled and recompleted
over the next 5 years. The total booked locations represent less than 10
percent of the potential drilling inventory identified in the PSA.

2017 Budget

The Company has submitted a 2017 budget to SOCAR including $21 million of
capital expenditures and $28 million of operating costs for 2017. A significant
portion of the capital and operating costs will be directed toward recompleting
13 wells in the Bahar Gas Field and 20 wells in the Gum Deniz Oil Field. The
capital budget also includes refurbishment of five platforms in the Bahar Gas
Field and two platforms in the Gum Deniz Oil field. The Company plans to
execute on this 2017 program while delivering continued efficiencies and cost
savings, which are expected to be repeatable. With a focus on growing gas
production in the near term, production is forecast to end the year at
approximately 6,444 boe/d compared to 4,185 boe/d in December 2016.

John W. Harkins, President and CEO of Greenfields, stated: “The 2017 BEOC
budget allows the Bahar project to provide adequate positive cash flows to fund
the project’s on-going operating costs and capital programs in the current oil
price environment of approximately $50 per barrel. Although our focus remains
on long term oil production growth from the project, the recent five-year
extension of our gas sales contract through December 2022 provides strong gas
sales in the near term for the project.”

About Greenfields Petroleum Corporation

Greenfields is a junior oil and natural gas corporation focused on the
development and production of proven oil and gas reserves principally in the
Republic of Azerbaijan. The Company plans to expand its oil and gas assets
through further farm-ins and acquisitions of Production Sharing Agreements from
foreign governments containing previously discovered but under-developed
international oil and gas fields, also known as “greenfields”. More information
about the Company may be obtained on the Greenfields website at
www.greenfields-petroleum.com.

Forward-Looking Statements

This press release contains forward-looking statements. More particularly, this
press release may include, but is not limited to, statements concerning: the
Protocol; the repayment of amounts to BEL; SOA’s monthly cash call obligation;
the Amended GSA; payment obligations under the ERDPSA, the Protocol and the
Amended GSA; the 2017 budget; 2017 capital expenditures; development costs;
operating plans; production forecast; and the adequacy of future cash flows and
funding on operations. Statements relating to “reserves” are also deemed to be
forward-looking statements, as they involve the implied assessment, based on
certain estimates and assumptions, that the reserves described exist in the
quantities predicted or estimated and that the reserves can be profitably
produced in the future. In addition, the use of any of the words “can”, “will”,
“estimate”, “long term”, “anticipate”, “believe”, “should”, “forecast”,
“future”, “continue”, “may”, “expect”, and similar expressions are intended to
identify forward-looking statements. The forward-looking statements contained
herein are based on certain key expectations and assumptions made by the
Company, including, but not limited to, expectations and assumptions concerning
the success of optimization and efficiency improvement projects, the
availability of capital, current legislation, receipt of required regulatory
approval, the success of future drilling and development activities, the
performance of existing wells, the performance of new wells, general economic
conditions, availability of required equipment and services, weather conditions
and prevailing commodity prices. Although the Company believes that the
expectations and assumptions on which the forward-looking statements are based
are reasonable, undue reliance should not be placed on the forward-looking
statements because the Company can give no assurance that they will prove to be
correct.

Since forward-looking statements address future events and conditions, by their
very nature they involve inherent risks and uncertainties most of which are
beyond the control of Greenfields. Should one or more of these risks or
uncertainties materialize, or should assumptions underlying the forward-looking
information prove incorrect, actual results, performance or achievements could
vary materially from those expressed or implied by the forward-looking
information. These risks include, but are not limited to, risks associated with
the oil and gas industry in general (e.g., operational risks in development,
exploration and production; delays or changes in plans with respect to
exploration or development projects or capital expenditures; the uncertainty of
reserve estimates; the uncertainty of estimates and projections relating to
production, costs and expenses, and health, safety, political and environmental
risks), commodity price and exchange rate fluctuations, changes in legislation
affecting the oil and gas industry; uncertainties resulting from potential
delays or changes in plans with respect to exploration or development projects
or capital expenditures; and the ability of BEL to recover the costs owed to
BEL from SOA. Additional risk factors can be found under the heading “Risk
Factors” in Greenfields’ Annual Information Form and similar headings in
Greenfields’ Management’s Discussion & Analysis which may be viewed on
www.sedar.com.

Information Regarding Disclosure on Oil and Gas Reserves

The reserves data set forth above is based upon an independent reserves
assessment and evaluation prepared by GLJ with an effective date of December
31, 2016 (the “GLJ Report”). The news release summarizes the Company’s crude
oil and natural gas reserves and the net present values before income tax of
future net revenue for the Company’s reserves using forecast prices and costs
based on the GLJ Report. All reserve references in this news release are based
on gross reserves, which are equal to the Company’s total working interest
reserves before the deduction of any royalties and including any royalty
interests of the Company. The GLJ Report has been prepared in accordance with
the standards contained in the COGE Handbook and the reserve definitions
contained in NI 51-101. All evaluations and reviews of future net cash flows
are stated prior to any provisions for interest costs or general and
administrative costs and after the deduction of estimated future capital
expenditures for wells to which reserves have been assigned. It should not be
assumed that the estimates of future net revenues presented in the tables above
represent the fair market value of the reserves. There is no assurance that the
forecast prices and cost assumptions will be attained and variances could be
material. The recovery and reserve estimates of the Company’s crude oil and
natural gas reserves provided herein are estimates only and there is no
guarantee that the estimated reserves will be recovered. Actual crude oil,
natural gas and natural gas liquids reserves may be greater than or less than
the estimates provided herein. All future net revenues are estimated using
forecast prices, arising from the anticipated development and production of the
Company’s reserves, net of the associated royalties, operating costs,
development costs, and abandonment and reclamation costs and are stated prior
to provision for interest and general and administrative expenses. Future net
revenues have been presented on a before tax basis. Estimated values of future
net revenue disclosed herein do not represent fair market value. Future
development costs are calculated as the sum of development capital plus the
change in future development costs for the period. The reserve data provided in
this news release only represents a summary of the disclosure required under NI
51-101. Additional disclosure will be provided in the Company’s Annual
Information Form which will be filed on www.sedar.com prior to May 1, 2017.

Notes to Oil and Gas Disclosures

“Possible reserves” means those additional reserves that are less certain to be
recovered than probable reserves. There is a 10% probability that the
quantities actually recovered will equal or exceed the sum of proved plus
probable plus possible reserves.

Barrels Oil Equivalent or “boe” may be misleading, particularly if used in
isolation. All volumes disclosed in this press release use a 6mcf: 1boe, as
such is typically used in oil and gas reporting and is based on an energy
equivalency conversion method primarily applicable at the burner tip and does
not represent a value equivalency at the wellhead. The Company uses a 6mcf:
1boe ratio to calculate its share of entitlement sales from the Bahar Project
for its financial reporting and reserves disclosure.

– END RELEASE – 24/04/2017

For further information:
Greenfields Petroleum Corporation
John W. Harkins
Chief Executive Officer
(832) 234-0836
OR
Greenfields Petroleum Corporation
A. Wayne Curzadd
Chief Financial Officer
(832) 234-0835
OR
www.greenfields-petroleum.com
info@greenfieldspetroleum.com

COMPANY:
FOR: GREENFIELDS PETROLEUM CORPORATION
TSX VENTURE SYMBOL: GNF

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170424CC0019

Press Release from Marketwired 1-866-736-3779

Zargon Oil & Gas Ltd. Announces Board of Directors Changes

April 24, 2017 by The Canadian Press

FOR: ZARGON OIL & GAS LTD.
TSX SYMBOL: ZAR
TSX SYMBOL: ZAR.DB

Date issue: April 24, 2017
Time in: 7:00 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 24, 2017) – K. James Harrison has
advised Zargon (TSX:ZAR)(TSX:ZAR.DB.A) that he does not intend to stand for
reelection for the Zargon Board of Directors at the upcoming Annual and Special
Meeting of Shareholders to be held on May 30, 2017. K. James Harrison has been
a director of Zargon since 1995, and his energy and counsel over the years have
been invaluable. On behalf of the management and Board of Directors of Zargon,
we would like to thank K. James Harrison for his significant contributions, and
we wish him the best in his future endeavours.

Zargon is pleased to announce that Kyle Kitagawa, who currently serves on
Zargon’s Board, has agreed to take on the Chairman of the Board
responsibilities upon Mr. Harrison’s retirement. Kyle Kitagawa brings over 20
years of experience in commodity trading, equity investing, and structured
finance in energy and energy intensive industries. Prior to April 2003, he held
senior executive positions in a global energy trading and capital corporation.
Currently, Mr. Kitagawa is Chairman of the Board of Directors of Canadian
Energy Services & Technology Corp. Prior directorships include Advanced Mobile
Power Systems, LLC, Esprit Exploration Ltd., Ferus Trust, Independent Energy
Ltd., Invasion Energy Inc., Livingston Energy Ltd., Papier Masson Ltee.,
ProspEx Resources Ltd., Wave Energy Ltd. and Coral Hill Energy Ltd. He holds a
Master of Business Administration degree from Queen’s University, a Bachelor of
Commerce from the University of Calgary and is a Chartered Accountant.

FURTHER INFORMATION

Zargon is a Calgary based oil and natural gas company working in the Western
Canadian and Williston sedimentary basins and is focused on oil exploitation
projects (waterfloods and tertiary ASP) that profitably increase oil production
and recovery factors from existing oil reservoirs.

In order to learn more about Zargon, we encourage you to visit Zargon’s website
at www.zargon.ca where you will find a current shareholder presentation,
financial reports and historical news releases.

ADVISORY ON FORWARD-LOOKING STATEMENTS

This press release contains forward-looking statements. More particularly, this
press release contains statements concerning the results of the Annual and
Special Meeting of Shareholders to be held on May 30, 2017. Although management
believes that the expectations reflected in the forward-looking statements are
reasonable, it cannot guarantee future results, performance or achievement
since such expectations are inherently subject to significant business,
economic, operational, competitive, political and social uncertainties and
contingencies. As a consequence, actual results may differ materially from
those anticipated in the forward looking statements. These forward-looking
statements involve substantial known and unknown risks and uncertainties,
certain of which are beyond Zargon’s control, and many factors could cause
Zargon’s actual results to differ materially from those expressed or implied in
any forward-looking statements made by the Company, including, but not limited
to: the Company and its financial position, liquidity and outlook; and other
risks and uncertainties described from time to time in the reports and filings
made with securities regulatory authorities by the Company. Readers are
cautioned that the foregoing list of important factors is not exhaustive.

Such forward-looking statements are based on certain assumptions made by Zargon
in light of its experience and perception of current conditions and expected
future developments, as well as other factors the Company believes are
appropriate in the circumstances, including, but are not limited to: that
Zargon will have the financial ability to satisfy its obligations; and other
matters.

The forward-looking statements contained in this press release are made as of
the date hereof and Zargon undertakes no obligation to update publicly or
revise any forward-looking statements or information, whether as a result of
new information, future events or otherwise, unless so required by applicable
securities laws.

– END RELEASE – 24/04/2017

For further information:
Zargon Oil & Gas Ltd.
C.H. Hansen
President and Chief Executive Officer
403-264-9992
zargon@zargon.ca
www.zargon.ca

COMPANY:
FOR: ZARGON OIL & GAS LTD.
TSX SYMBOL: ZAR
TSX SYMBOL: ZAR.DB

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170424CC0011

Press Release from Marketwired 1-866-736-3779

Precision Drilling Corporation Announces 2017 First Quarter Financial Results – Part 1

April 24, 2017 by The Canadian Press

FOR: PRECISION DRILLING CORPORATIONTSX SYMBOL: PDNYSE SYMBOL: PDSDate issue: April 24, 2017Time in: 6:00 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 24, 2017) – Precision Drilling
Corporation (TSX:PD)(NYSE:PDS) – (Canadian dollars except as i…

Precision Drilling Corporation Announces 2017 First Quarter Financial Results – Part 4

April 24, 2017 by The Canadian Press

Adjusted EBITDA
We believe that adjusted EBITDA (earnings before income taxes, gain on
repurchase of unsecured senior notes, financing charges, foreign exchange and
depreciation and amortization), as reported in the Interim Consolidated
Statement of Lo…

Change of Hong Kong Company Secretary and Authorised Representative

April 23, 2017 by The Canadian Press

FOR: SUNSHINE OILSANDS LTD.HKSE SYMBOL: 2012Date issue: April 24, 2017Time in: 5:27 AM eAttention:
HONG KONG, CHINA and CALGARY, ALBERTA–(Marketwired – April 24, 2017) –
Sunshine Oilsands Ltd. (the “Corporation” or “Sunshine”) (HKSE:2012) wishes to
an…

WesternZagros Announces Deferral of Draw Date on Debt Facility

April 23, 2017 by The Canadian Press

FOR: WESTERNZAGROS RESOURCES LTD.TSX VENTURE SYMBOL: WZRDate issue: April 23, 2017Time in: 11:08 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 23, 2017) –
NOT FOR DISTRIBUTION TO U.S. NEWSWIRE SERVICES OR DISSEMINATION IN THE UNITED
STATES
West…

RTDNA Canada announces BC region award winners

April 22, 2017 by The Canadian Press

FOR: RTDNA CANADA
Date issue: April 23, 2017Time in: 1:00 AM eAttention:
VANCOUVER, BRITISH COLUMBIA–(Marketwired – April 23, 2017) – RTDNA Canada is
pleased to recognize journalistic excellence with the winners of the British
Columbia Region RTDNA Aw…

BC’s Search and Rescue Organizations Salute Their Volunteers During National Volunteer Week

April 22, 2017April 22, 2017 by The Canadian Press

FOR: ROYAL CANADIAN MARINE SEARCH AND RESCUE

VICTORIA, British Columbia, April 22, 2017 (GLOBE NEWSWIRE) — British Columbia’s ground, air and marine search and rescue organizations are recognizing their more than 4,400 volunteers during National Volunteer Week (April 23 – 29). The province’s search and rescue (SAR) volunteers are among more than 12 million volunteers across Canada who devote time and energy to benefiting their communities.

The volunteers are represented by Royal Canadian Marine Search and Rescue, the BC Search and Rescue Association, and PEP Air. The three organizations work in partnership to support the federal, provincial and local agencies which call upon volunteers to respond during emergencies.

Across British Columbia, SAR crews are standing by 24 hours a day. Marine rescue crews are ready to brave B.C.’s challenging waters to help mariners in distress. Ground search teams are ready to search for missing hikers in rugged terrain. Volunteer pilots and crews are ready to take to the air to search for missing people and aircraft. SAR volunteers collectively respond to more than 2,000 incidents every year in B.C., saving many lives. They also engage the public through education programs to help prevent tragedies.

“National Volunteer Week is an opportunity to recognize the tremendous contributions of search and rescue volunteers towards public safety in British Columbia,” said Pat Quealey, CEO of Royal Canadian Marine Search and Rescue. “We are proud to be part of the vibrant volunteer community across Canada, helping to make our communities safe and strong.”

“BC’s highly-skilled SAR volunteers devote more than 280,000 hours every year towards training and missions,” said Chris Kelly, President of the BC Search and Rescue Association. “We are driven by a spirit of volunteerism and are pleased to dedicate our time and knowledge to helping the public.”

“During National Volunteer Week we are encouraging people to say thanks to their neighbours who volunteer as air, ground and marine rescuers,” said Alton King, Director General of PEP Air. “Throughout British Columbia they are a powerful force for safety, and they deserve our applause.”

Royal Canadian Marine Search and Rescue – www.rcmsar.com

BC Search and Rescue Association – www.bcsara.com

PEP Air – www.embc-air.org

FOR FURTHER INFORMATION PLEASE CONTACT:

Contact: 778 352-1006 media@rcmsar.com

INDUSTRY:

Miscellaneous – Miscellaneous

SUBJECT: CALMIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Contact: 778 352-1006 media@rcmsar.com}

Globenewswire

Arbutus Announces ARB-1467 Data Presentation at EASL

April 22, 2017April 22, 2017 by The Canadian Press

FOR: ARBUTUS BIOPHARMA CORPORATION

ARB-1467 Reduces Serum HBsAg in Both HBeAg Negative and HBeAg Positive PatientsResults of Biweekly Dosing from Cohort 4 Expected in 3Q17Additional Study Starting in 2H17 to Evaluate Longer Term Dosing with Immune Modulatory Agents

VANCOUVER, British Columbia and WARMINSTER, Pa., April 22, 2017 (GLOBE NEWSWIRE) — Arbutus Biopharma Corporation (Nasdaq:ABUS), an industry-leading Hepatitis B Virus (HBV) therapeutic solutions company, presented results of the first three cohorts of a Phase II study of its RNAi agent, ARB-1467, at the European Association for the Study of the Liver (EASL) in Amsterdam, The Netherlands.

“We are very pleased to present updated Phase II results for ARB-1467 that show a consistent reduction in HBsAg in HBV patients regardless of HBeAg status with a favorable safety profile. We look forward to a 3Q17 announcement of the results of Cohort 4, which is evaluating five bi-weekly doses of ARB-1467 with extended monthly dosing out to one year for patients who meet predefined response criteria,” said Dr. Mark J. Murray, Arbutus’ President and CEO. “Furthermore, we are planning to initiate a new study of ARB-1467 in 2H17 to evaluate longer dosing of ARB-1467 combined with immunomodulatory agent. We believe that this study could pave the way for Phase IIb studies while we continue to advance the rest of our pipeline to enable new treatment regimens for further improvement in clinical outcomes.”

The presentation is titled “A Phase 2a Study Evaluating the Multi-Dose Activity of ARB-1467 in HBeAg Positive and Negative Virally Suppressed Subjects with Hepatitis B”, and a copy of the poster can be accessed by visiting the Investor section of www.arbutusbio.com and selecting ‘Events and Presentations.’

Cohort	ARB-1467 (mg/kg)	HBeAg	Single Dose HBsAg Reduction (log10 IU/mL)				Multiple Dose HBsAg Reduction (log10 IU/mL)
Cohort	ARB-1467 (mg/kg)	HBeAg	N	Meana	Mean Maxb	Maxc	N	Meana	Mean Maxb	Maxc	>0.5 logd	>1.0 logd
1	0.2	Neg	6	-0.3	-0.4	-1.0	6	-0.6	-0.7	-1.3	5	1
2	0.4	Neg	6	-0.2	-0.3	-0.8	5e	-0.8	-0.9	-1.1	4	3
3	0.4	Pos	6	-0.2	-0.3	-0.6	6	-0.7	-0.8	-1.6	4	2
Placebo		All	6f	0.0	0.0	-0.1	6	0.0	-0.1	-0.1	0	0

a The mean serum HBsAg reduction is the nadir value of the arithmetic mean of all values observed at each time point.b The mean maximum HBsAg reduction is the mean of each patient’s maximum reduction in serum HBsAg. c Maximum HBsAg reduction is the best single reduction among all patients in a cohort.d Number of patients reaching this thresholde Multiple dose results in Cohort 2 exclude one patient that discounted at day 36 due to an acute hepatitis E virus (HEV) super-infectionf Placebo results are based on six subjects (two from each cohort).

ARB-1467 Phase 2 Trial DesignThe Phase II trial is a multi-dose study in chronic HBV patients who are also receiving stable nucleot(s)ide analog therapy. The trial consists of four cohorts, the first three of which enrolled eight subjects each (six receiving three monthly doses of ARB-1467 and two receiving placebo) and the fourth is enrolling twelve patients (all of whom will receive 5 bi-weekly doses of ARB-1467). Cohorts 1, 2, and 4 include HBeAg- patients and Cohort 3 included HBeAg+ patients. The protocol for Cohort 4 allows for dosing to be extended to up to one year of ARB-1467 dosing for patients who meet predefined response criteria.

Next Steps for ARB-1467In addition to the ongoing Phase 2 Cohort 4, Arbutus will initiate a new study in 2H17 to study longer term dosing of ARB-1467 in combination with nucleot(s)ide analog therapy as well as pegylated interferon or another immune modulator. This study will explore the possibility of driving HBsAg to very low, if not undetectable, levels with ARB-1467 along with an immune modulating mechanism. While this study may include pegylated interferon as the immune boosting component that could lead to later stage development, Arbutus also plans to evaluate other immunomodulatory approaches, such as its proprietary checkpoint inhibitor program, in future combination studies. Arbutus’ core protein/capsid inhibitor AB-423, which is being evaluated for monotherapy safety and activity in 2017, will be ready to be included in studies with RNAi and approved agents in 2018. ARB-1740, a next generation RNAi agent, is being evaluated in an ongoing multi-dosing study in HBV patients, the results of which will be announced in 2H17 to enable a potency comparison between ARB-1467 and ARB-1740.

About ARB-1467Arbutus’ RNAi candidate ARB-1467 comprises three RNAi triggers that target all four HBV transcripts, and has been shown in preclinical studies to reduce all viral antigen levels as well as cccDNA and HBV DNA. ARB-1467 utilizes Arbutus’ proprietary lipid nanoparticle (LNP) platform, a clinically validated delivery technology which has been tested in hundreds of patients.

About Arbutus

Arbutus Biopharma Corporation is a biopharmaceutical company dedicated to discovering, developing and commercializing a cure for patients suffering from chronic HBV infection. Arbutus is headquartered in Vancouver, BC, and has facilities in Warminster, PA. For more information, visit www.arbutusbio.com.

Forward-Looking Statements and Information

This press release contains forward-looking statements within the meaning of the Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934, and forward looking information within the meaning of Canadian securities laws (collectively, “forward-looking statements”). Forward-looking statements in this press release include statements about announcing multi-dosing results of the fourth cohort of the Phase II study of ARB-1467 in 3Q17; a the format of a new study of ARB-1467 in 2H17 to evaluate longer dosing of ARB-1467 combined with immunomodulatory agent, and potentially paving the way for Phase IIb studies; including Arbutus’ core protein/capsid inhibitor, AB-423, in studies with RNAi and approved agents in 2018; announcing the results of an ongoing multi-dosing study of ARB-1740 in HBV patients in 2H17; continuing to advance the rest of our pipeline to enable new treatment regimens for further improvement in clinical outcomes; and developing a portfolio of HBV assets to ultimately cure HBV through combination therapy.

With respect to the forward-looking statements contained in this press release, Arbutus has made numerous assumptions regarding, among other things: the effectiveness and timeliness of clinical trials, and the usefulness of the data; the continued demand for Arbutus’ assets; and the stability of economic and market conditions. While Arbutus considers these assumptions to be reasonable, these assumptions are inherently subject to significant business, economic, competitive, market and social uncertainties and contingencies.

Additionally, there are known and unknown risk factors which could cause Arbutus’ actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by the forward-looking statements contained herein. Known risk factors include, among others: anticipated clinical trials may be more costly or take longer to complete than anticipated, and may never be initiated or completed, or may not generate results that warrant future development of the tested drug candidate; Arbutus may not receive the necessary regulatory approvals for the clinical development of Arbutus’ products; economic and market conditions may worsen; and market shifts may require a change in strategic focus.

A more complete discussion of the risks and uncertainties facing Arbutus appears in Arbutus’ Annual Report on Form 10-K and Arbutus’ continuous disclosure filings, which are available at www.sedar.com and at www.sec.gov. All forward-looking statements herein are qualified in their entirety by this cautionary statement, and Arbutus disclaims any obligation to revise or update any such forward-looking statements or to publicly announce the result of any revisions to any of the forward-looking statements contained herein to reflect future results, events or developments, except as required by law.

FOR FURTHER INFORMATION PLEASE CONTACT:

Contact Information Investors Adam Cutler Senior Vice President, Corporate Affairs Phone: 604-419-3200 Email: acutler@arbutusbio.com Tiffany Tolmie Manager, Investor Relations Phone: 604-419-3200 Email: ttolmie@arbutusbio.com Media David Schull Russo Partners Phone: 858.717.2310 Email: david.schull@russopartnersllc.com

INDUSTRY:

Pharmaceuticals and Biotech – Drugs

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Contact Information Investors Adam Cutler Senior Vice President, Corporate Affairs Phone: 604-419-3200 Email: acutler@arbutusbio.com Tiffany Tolmie Manager, Investor Relations Phone: 604-419-3200 Email: ttolmie@arbutusbio.com Media David Schull Russo Partners Phone: 858.717.2310 Email: david.schull@russopartnersllc.com}

Globenewswire

NAV CANADA reports March traffic figures

April 22, 2017April 21, 2017 by The Canadian Press

FOR: NAV CANADA

OTTAWA, April 21, 2017 (GLOBE NEWSWIRE) — NAV CANADA announced today its traffic figures for the month of March 2017 as measured in weighted charging units for en-route, terminal and oceanic air navigation services, in comparison to the last fiscal year.

The traffic in March 2017 increased by an average of 5.9 per cent compared to the same month in 2016.

Fiscal 2017 year-to-date traffic was 4.9 per cent higher than in the prior fiscal year. NAV CANADA’s fiscal year runs from September 1 to August 31.

Weighted charging units represent a traffic measure that reflects the number of flights, aircraft size and distance flown in Canadian airspace.

The information contained in this news release is also available in graph form.

NAV CANADA is the country’s private sector civil air navigation services provider. With operations from coast to coast to coast, NAV CANADA provides air traffic control, flight information, weather briefings, aeronautical information services, airport advisory services and electronic aids to navigation.

FOR FURTHER INFORMATION PLEASE CONTACT:

For further information, please contact: Michelle Bishop Director, Government and Public Affairs (613) 563-7520 Ron Singer National Manager, Media Relations (613) 563-7303 Media Information Line: 1-888-562-8226

INDUSTRY:

Aerospace and Defense – Aircraft

SUBJECT: PDT

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: For further information, please contact: Michelle Bishop Director, Government and Public Affairs (613) 563-7520 Ron Singer National Manager, Media Relations (613) 563-7303 Media Information Line: 1-888-562-8226}

Globenewswire

Trilogy International Partners Prices US $350 million of Senior Secured Notes

April 22, 2017April 21, 2017 by The Canadian Press

FOR: TRILOGY INTERNATIONAL PARTNERS LLC

BELLEVUE, Wash., April 21, 2017 (GLOBE NEWSWIRE) — Trilogy International Partners Inc. (TSX:TRL) (“TIP Inc.”) today announced that its subsidiaries, Trilogy International Partners LLC (“Trilogy LLC”) and Trilogy International Finance Inc. (the “Co-Issuer” and, together with Trilogy LLC, the “Issuers”), priced their private offering of US $350 million aggregate principal amount of senior secured notes (the “Notes”). The Notes will bear interest at a rate of 8.875% per annum, will be issued at 99.506% of their face value and mature in 2022.

The Notes will be guaranteed by certain of Trilogy LLC’s US-domiciled subsidiaries. The Notes will be secured by (x) a first-priority lien on the equity interests of the Co-Issuer and the guarantors of the notes and (y) a pledge of any intercompany indebtedness owed to Trilogy LLC or any guarantor by Trilogy LLC’s New Zealand subsidiary, Two Degrees Mobile Limited (“2degrees”) or any of 2degrees’ subsidiaries and certain third party indebtedness owed to Trilogy LLC by any minority shareholder in 2degrees.

The offering of the Notes is expected to close on May 2, 2017, subject to satisfaction of customary closing conditions.

The Issuers intend to apply the proceeds of this offering, together with cash on hand, to redeem all of their outstanding 13.375% senior secured notes due 2019 and pay fees and expenses related to this offering.

The Notes are being offered in a private offering exempt from the registration requirements of the United States Securities Act of 1933, as amended (the “Securities Act”). The Notes will be offered only to persons reasonably believed to be qualified institutional buyers in reliance on Rule 144A under the Securities Act, and outside the United States, only to non-U.S. investors pursuant to Regulation S. The Notes will not be registered under the Securities Act or any state securities laws and may not be offered or sold in the United States absent an effective registration statement or an applicable exemption from, or a transaction not subject to, the registration requirements of the Securities Act and applicable state securities laws. This news release does not constitute an offer to sell or a solicitation of an offer to buy any of the Notes, nor does it constitute an offer, solicitation or sale in any jurisdiction in which such offer, solicitation or sale is unlawful. Any offer of the Notes will be made only by means of a private offering memorandum.

Cautionary Statements

This News Release contains “forward-looking information” and “forward looking statements” within the meaning of applicable Canadian and United States securities legislation. Statements contained herein that are not based on historical or current fact, including without limitation statements containing the words “anticipates,” “believes,” “may,” “continues,” “estimates,” “expects,” and “will” and words of similar import, constitute “forward-looking statements” within the meaning of the U.S. Private Securities Litigation Reform Act of 1995. Forward-looking information may include, but is not limited to, the proposed offering, the terms of the Notes and the anticipated use of proceeds. Wherever possible, words such as “plans”, “expects”, “projects”, “assumes”, “budget”, “strategy”, “scheduled”, “estimates”, “forecasts”, “anticipates”, “believes”, “intends”, “targets” and similar expressions or statements that certain actions, events or results “may”, “could”, “would”, “might” or “will” be taken, occur or be achieved, or the negative forms of any of these terms and similar expressions, have been used to identify forward-looking statements and information. Any statements that express or involve discussions with respect to predictions, expectations, beliefs, plans, projections, objectives, assumptions or future events or performance are not statements of historical fact and may be forward-looking information. Forward-looking information is subject to a variety of known and unknown risks, uncertainties and other factors that could cause actual events or results to differ from those expressed or implied by the forward-looking information, including, without limitation, risks relating to the need to satisfy the conditions set forth in the purchase agreement for the Notes, the need to satisfy regulatory and legal requirements with respect to the offering and those risks identified in TIP Inc.’s Annual Information Form dated March 27, 2017 filed on SEDAR at www.sedar.com and in the United States on Form 40-F through EDGAR at the SEC’s website at www.sec.gov. Forward-looking information is based on the expectations and opinions of TIP Inc.’s management on the date the statements are made. The assumptions used in the preparation of such statements, although considered reasonable at the time of preparation, may prove to be imprecise. We do not assume any obligation to update forward-looking information, whether as a result of new information, future events or otherwise, other than as required by applicable law. For the reasons set forth above, prospective investors should not place undue reliance on forward-looking information.

About Trilogy International Partners Inc.

Trilogy International Partners Inc. (TSX:TRL) is the parent company of Trilogy International Partners LLC, a wireless telecommunications operator formed by wireless industry pioneers John Stanton, Theresa Gillespie and Brad Horwitz. Trilogy’s founders have an exceptional track record of successfully buying, building, launching and operating communication businesses in 15 international markets.

Trilogy currently provides wireless communications services through its operating subsidiaries in New Zealand and Bolivia. Its head office is located at 155 108th Avenue NE, Suite 400, Bellevue, Washington, 98004 USA.

For more information, visit www.trilogy-international.com.

FOR FURTHER INFORMATION PLEASE CONTACT:

CONTACT: Trilogy International Partners Inc. Ann Saxton Vice President, Investor Relations & Corporate Development +1 (425) 458-5900

INDUSTRY:

Telecom – Wireless/Mobile

SUBJECT: STK

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: CONTACT: Trilogy International Partners Inc. Ann Saxton Vice President, Investor Relations & Corporate Development +1 (425) 458-5900}

Globenewswire

Housing, emissions and children: three ways politics touched Canadians this week

April 22, 2017April 21, 2017 by The Canadian Press

OTTAWA — Save for the several thousand pot-smoking protesters who lit up outside the Peace Tower on Thursday, Parliament Hill was an island of quiet this week — even as global forces battered the country’s sense of security.

MPs were mainly in their ridings for the Easter break, and several cabinet ministers were south of the border preaching the wonders of the federal agenda.

But reminders of the unpredictability of powerful international events hailed down around them, with terrorists striking again in Paris and U.S. President Donald Trump suddenly turning his protectionist wrath on the “disgrace” that is Canada.

At the same time, there were concrete developments on housing, greenhouse gas emissions and the rights of children. Here are a few ways federal politics touched us this week:

DEFLATING THE BUBBLE?

When decision-makers from three levels of government met Monday in Toronto to discuss that region’s runaway housing prices, the takeaway was an agreement to do no harm.

Federal Finance Minister Bill Morneau, his provincial counterpart Charles Sousa and Toronto Mayor John Tory made a pact to refrain from doing anything that would drive prices even higher. The pact would preclude boosting incentives for first-time homebuyers — always tempting when an election is at hand.

After agreeing on what not to do, the politicians turned individually to what actions they could take to cool the Toronto-area market without destroying wealth and stability elsewhere in the country.

Ontario made the biggest splash, rolling out 16 measures, including a 15-per-cent tax on foreign homebuyers and stiffer rent controls.

But there is little agreement on what the root causes of the surging prices are. Tory talks about strong economic growth attracting attention. Ontario’s measures suggest foreign buying is to blame. The head of the Canada Mortgage and Housing Corp. says it’s not all foreigners. And the federal government, after studying the alarming market dynamics in Toronto and Vancouver for years, is collecting more data, which suggests it still doesn’t know exactly what is going on.

GASSY POLITICS

The Trudeau government’s best-laid plans on climate change are running into some friction.

The Conservatives asked the Library of Parliament to figure out how much revenue the federal government was collecting off provincial carbon taxes in Alberta and British Columbia.

The answer came this week: $280 million over the next two years, despite Ottawa’s arguments that carbon taxes would be revenue neutral for the federal books. The figure prompted an outcry from the Conservatives, many of whom are dead-set against federal plans to promote carbon taxes.

Then came word that worries about Trump and his new approach to climate change were prompting a slowdown in plans to cut emissions from methane.

Last year, to much fanfare, Trudeau and then-U.S. President Barack Obama agreed to chop methane emissions by more than 40 per cent from 2012 levels by 2025 by cracking down on the oil and gas sector.

Since then, Trump has rolled back some of Obama’s climate provisions. Trudeau’s government has said repeatedly it would stick to its plans, regardless of Trump. But on Friday, Natural Resources Minister Jim Carr said competitiveness with the U.S. has pushed Canada to take a second look at the methane commitment and to proceed more slowly.

CHILDREN AND THEIR RIGHTS

The Canadian Human Rights Commission, a watchdog that hears complaints from the public and can take them to court, has issued its 2016 report and is raising the alarm about the protection of the rights of children.

The commission has gone to bat for years for First Nations children on reserve, arguing they receive substandard social services. Now, the commission is expanding its glare to immigrant children held in detention, children who are struggling with gender identity and children who are bullied because of their disabilities.

Indeed, more than half of the complaints received by the commission in 2016 were related to disability, and almost half of those were linked to mental health.

The government says it is working hard on all fronts.

Heather Scoffield, Ottawa Bureau Chief, The Canadian Press

Canada delays methane regulations for three years following U.S. retreat

April 21, 2017April 21, 2017 by The Canadian Press

OTTAWA — Canada is going to put off for three years its plan to regulate cuts to methane emissions in the oil and gas sector.

The move comes less than a month after U.S. President Donald Trump signed an executive order that hits the pause button on matching American commitments to methane cuts — and the timing is no coincidence.

Canada can’t ignore the U.S. if it wants to preserve the competitiveness of its oil and gas industry and commitments to sustainable energy, Natural Resources Minister Jim Carr told The Canadian Press in an interview Friday.

“We have to keep a very close eye on what our American partners do because the economies are so interlinked,” he said.

In January 2015, then-U.S. President Barack Obama announced a plan to slash methane emissions from the U.S. oil and gas sector between 40 and 45 per cent over 2012 levels by 2025. Canada agreed to match that in March 2016, when Prime Minister Justin Trudeau had a state visit to Washington.

The United States issued initial regulatory standards in May 2016 and issued new reporting requirements for companies to submit data on equipment and operations to better track methane emissions.

Then the government changed.

In early March, the Environmental Protection Agency eliminated those new reporting requirements. Weeks later, Trump signed an executive order requiring that the methane emissions standards be re-evaluated.

Canada was to issue its first regulations this spring and they were to be implemented between 2018 and 2020.

Marie-Pascale Des Rosiers, a spokeswoman for Environment Minister Catherine McKenna, confirmed this week the government has agreed to postpone the regulations several years. Now they won’t begin until 2020 and won’t be fully in place until 2023.

The government is, however, sticking with its commitment to cut methane emissions 40 to 45 per cent over 2012 levels by 2025.

“This change to the start date will allow industry more time to make changes to operations, and to budget the capital needed,” Des Rosiers said.

“The shifted timing will also allow provinces time to finalize their provincial methane regulations for discussions on equivalency.”

Vicky Ballance, director of climate and innovation for the Canadian Association of Petroleum Producers, said her organization’s biggest concerns were about giving industry the time to meet the requirements.

“We are still 100 per cent committed to meeting that target,” notwithstanding what happens in the U.S., Ballance said.

McKenna was in California this week on a trade mission and climate change industry tour. She told a conference call Thursday that the decision was the result of listening to industry in a “smart and thoughtful way.”

“We are absolutely steadfast in reducing emissions in the oil and gas sector including methane,” said McKenna.

Canada actually has to play catch up with state-level regulations on methane emissions, said McKenna.

That is one reason environmental experts are disappointed in the regulatory delay.

Dale Marshall, national program manager of Environmental Defence, said Friday he is angry the regulations are being pushed back — especially if it is because of a U.S. decision to abandon their targets.

“Deciding that we are going to tie our boat, tie our wagon to the Trump administration on climate change is crazy,” he said. “This is the one measure that the oil and gas sector faces in the pan Canadian framework.”

— Follow @mrabson on Twitter

Mia Rabson, The Canadian Press

Cenovus plans to accelerate drilling on acquired ConocoPhillips gas properties

April 21, 2017 by The Canadian Press

CALGARY — Cenovus Energy (TSX:CVE) plans to ramp up the drilling of conventional gas wells on the lands it is buying from Houston-based ConocoPhillips in a $17.7-billion deal announced last month.

The Calgary-based company intends to spend $650 million in 2019 to drill about 120 wells in what is known as the Deep Basin of northeastern B.C. and northwestern Alberta, CEO Brian Ferguson said in an interview on Friday.

That’s about five times the $120 million ConocoPhillips had planned to spend this year to drill 24 wells, he said.

The drilling will bring on new production to better utilize ConocoPhillips’ gas processing plants and pipelines, Ferguson said, thus improving the economic return from the play.

“The infrastructure is 40 per cent utilized — that’s one of the big opportunities for us,” he said.

“Conoco has been starving the Deep Basin of capital; they had been allocating it elsewhere in the corporation.”

He said spending on the assets is expected to climb this year to $170 million and next year to $350 million.

Cenovus said production from the Deep Basin properties could grow by more than 40 per cent, from 120,000 barrels of oil equivalent per day in 2017 to about 170,000 boe/d in 2019.

Cenovus is also buying ConocoPhillips’s 50 per cent interest in the FCCL Partnership, an oilsands venture between the two companies in northern Alberta. The deal is expected to close by June 30.

The acquisitions will boost Cenovus’ production from 290,000 boe/d to 588,000 boe/d, with about 60 per cent of the total output coming from the oilsands.

ConocoPhillips has said it wanted to sell the Canadian assets to pay down debt and to allocate capital to other energy investments with better rates of return than oilsands and natural gas.

Ferguson believes the deal will provide cost-saving “operating synergies” for Cenovus, but said the effect on job numbers hasn’t yet been determined.

Cenovus said it has seen active interest from potential buyers of Alberta conventional oil and gas assets at Pelican Lake and Suffield it is trying to sell to help pay for the ConocoPhillips acquisition.

Follow @HealingSlowly on Twitter.

Dan Healing, The Canadian Press

US rig count rises 10 this week to 857; Texas up 6

April 21, 2017 by The Canadian Press

HOUSTON — The number of rigs exploring for oil and natural gas in the U.S. rose by 10 this week to 857.

A year ago, 431 rigs were active.

Houston oilfield services company Baker Hughes Inc. said Friday that 688 rigs sought oil and 167 explored for natural gas this week. Two were listed as miscellaneous.

Texas added six rigs and Alaska, Colorado, North Dakota, Pennsylvania and Wyoming each gained one.

Oklahoma lost one rig.

Arkansas, California, Kansas, Louisiana, New Mexico, Ohio, Utah and West Virginia were unchanged.

The U.S. rig count peaked at 4,530 in 1981. It bottomed out last May at 404.

The Associated Press

US Treasury rejects Exxon Mobil request to drill in Russia

April 21, 2017April 21, 2017 by The Canadian Press

WASHINGTON — The Trump administration has rejected a request from Exxon Mobil to waive U.S. sanctions against Russia to allow the company to resume oil drilling around the Black Sea.

Treasury Secretary Steven Mnuchin said Friday in a brief statement that the administration “will not be issuing waivers to U.S. companies, including Exxon, authorizing drilling prohibited by current Russian sanctions.”

Exxon said it understood the decision, while suggesting that the outcome will merely help European oil companies operating under less-stringent restrictions.

The decision comes just two days after it was reported that Exxon was seeking a waiver to resume a joint venture with Rosneft, a Russian state-owned oil company. Exxon said it filed the request in 2015.

The disclosure of Exxon’s application was criticized in Congress by lawmakers who said the Trump administration should not reduce sanctions after U.S. intelligence agencies concluded that Russia interfered in last year’s presidential election. Sen. John McCain, R-Ariz., tweeted of Exxon’s request, “Are they crazy?”

Secretary of State Rex Tillerson was Exxon’s CEO before joining President Donald Trump’s cabinet. While at Exxon, he cultivated close ties with Rosneft and Russian officials including President Vladimir Putin, and he spoke against sanctions that were imposed in 2014 in response to Russia’s annexation of the Crimea region of Ukraine.

The sanctions bar U.S. oil companies from transferring to Russia the advanced technology that is used to drill more efficiently offshore and in shale formations. Exxon has said in regulatory filings that the sanctions could lead to losses of up to $1 billion.

An Exxon spokesman said the company’s application for a waiver was made to meet contractual obligations under a joint-venture agreement in Russia, “where competitor companies are authorized to undertake such work under European sanctions.”

Rosneft officials have said that their joint venture with Italy’s Eni S.p.A. plans to begin drilling this year in the Black Sea next to the area where Exxon hoped to drill.

Under Treasury Department rules, ExxonMobil could resubmit its application if it provides additional information the government hadn’t reviewed previously.

Irving, Texas-based Exxon has disclosed receiving three waivers from the sanctions during the Obama administration for limited work with Rosneft.

Exxon’s critics urged the Treasury Department to block more waivers, which they feared would give new momentum to drilling in the environmentally sensitive Russian Arctic.

Shares of Exxon Mobil Corp. fell 32 cents to close Friday at $80.69.

___

Koenig reported from Dallas.

Christopher S. Rugaber And David Koenig, The Associated Press

Petro Vista Annouces Approval of Return of Capital

April 21, 2017 by The Canadian Press

FOR: PETRO VISTA ENERGY CORP.TSX VENTURE SYMBOL: PTVDate issue: April 21, 2017Time in: 6:28 PM eAttention:
VANCOUVER, BRITISH COLUMBIA–(Marketwired – April 21, 2017) – Petro Vista
Energy Corp. (TSX VENTURE:PTV) (“Petro Vista” or the “Company”), announ…

Husky Energy to Announce 2017 First Quarter Results / Webcast Annual Meeting of Shareholders

April 21, 2017 by The Canadian Press

FOR: HUSKY ENERGY INC.
TSX Symbol: HSE

Date issue: April 21, 2017
Time in: 6:00 PM e

Attention:

CALGARY, AB –(Marketwired – April 21, 2017) – Husky Energy (TSX: HSE) will
release its 2017 first quarter results before markets open on Friday, May 5,
2017. A conference call will be held the same day beginning at 8 a.m. Mountain
Time (10 a.m. Eastern Time).

CEO Rob Peabody, CFO Jon McKenzie and COO Rob Symonds will participate in the
call.

/T/

To listen live: To listen to a recording (after 10
a.m. May 5)

Canada and U.S. Toll Free: 1-800-319- Canada and U.S. Toll Free: 1-800-319-
4610 6413
Outside Canada and U.S.: 1-604-638- Outside Canada and U.S.: 1-604-638-
5340 9010
Passcode: 1316
Duration: Available until June 5, 2017
Audio webcast: Available for 90 days
at www.huskyenergy.com under Investor
Relations

/T/

Following the call, the Company will hold its Annual Meeting of Shareholders
at 10:30 a.m. Mountain Time in the Palomino Room at the BMO Centre, 20 Roundup
Way S.E., Calgary, Alberta.

A live webcast of the meeting will be available at www.huskyenergy.com under
Investor Relations. The archived webcasts of the conference call and the
meeting will be available for approximately 90 days.

Husky Energy is a Canadian-based integrated energy company. It is
headquartered in Calgary, Alberta, Canada and its common shares are publicly
traded on the Toronto Stock Exchange under the symbol HSE. More information is
available at www.huskyenergy.com

– END RELEASE – 21/04/2017

For further information:

For further information, please contact:

Investor Inquiries:

Rob Knowles
Manager, Investor Relations
Husky Energy Inc.
587-747-2116

Media Inquiries:

Mel Duvall
Manager, Media & Issues
Husky Energy Inc.
403-513-7602

COMPANY:
FOR: HUSKY ENERGY INC.
TSX Symbol: HSE

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170421CC010

Press Release from Marketwired 1-866-736-3779

Weekly Canadian Oil & Gas Industry Highlights – April 18, 2017

June 28, 2017April 21, 2017 by EnergyNow Media

April 18, 2017 Presented by POIM Consulting Group Major /Interesting Projects Canadian Natural Resources Limited adding Compressor to large Bitumen satellite battery 02-21-073-07W4 Cortona Energy Ltd. Adding 3 Oil satellite – multiwall 12-12-013-21W4 Velvet Energy Ltd large Gas battery – multiwall 16-18-054-17W5 Baytex Energy Corp. 4 new well license for 8-5-49-1W4 Pad site Seven Generations … Read more

Rover Parking named finalist for the Vision to Reality Innovator of the Year Award

April 22, 2017April 21, 2017 by The Canadian Press

FOR: ROVER PARKING

TORONTO, April 21, 2017 (GLOBE NEWSWIRE) — Rover Parking, Canada’s leading marketplace for shared, peer-to-peer parking proudly announces that it has been named an official finalist for the PWC Vision to Reality (V2R) Innovator of the Year Award, in the DISRUPTOR category.

Vision to Reality (V2R) Innovator of the Year Award is PwC Canada’s annual program aimed at recognizing and celebrating the most innovative organizations in the nation. Find out more about the program: www.pwc.com/ca/v2r and more about the finalists: www.pwc.com/ca/v2r/finalists

“This is a huge honour for us and something which we’re very proud to be a part of. Rover has been working tirelessly for over a year now on bringing a disruptive, yet more common sense approach to the parking and congestion challenges facing most Canadian cities. This award recognizes that what we are working on matters and is an important component of the make up for the smart cities of tomorrow,” said Grant Brigden, Co-Founder of Rover Parking.

“This year’s award finalists personify the potential Canada has to become a global innovation leader. PwC Canada is proud to shine the spotlight on companies who are reshaping the Canadian landscape by pushing boundaries and setting new benchmarks for excellence,” said Tahir Ayub, Managing Partner, Markets and Industries at PwC Canada.

To download the Rover Parking mobile app or learn more visit: roverparking.com

About Rover Parking Rover is Canada’s leading marketplace for shared parking. Often described as the airBNB of parking, Rover provides a brand new supply of private parking spaces that are easy to find, inexpensive, available all over the city and accessible from a few quick taps on a smartphone.

Rover allows individuals or businesses that have driveways or parking spaces that sit empty for hours on end, to share those spaces for a fee, resulting in some quick extra cash in hand.

The Rover Parking app can be downloaded for free on both iOS and Android at roverparking.com or via the App Store or Google Play.

FOR FURTHER INFORMATION PLEASE CONTACT:

Contact Information Grant Brigden – Co-Founder grant@roverparking.com 647.407.8986 Tim Wootton – Co-Founder tim@roverparking.com 416.710.7893

INDUSTRY:

Computers and Software – Hardware

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Contact Information Grant Brigden – Co-Founder grant@roverparking.com 647.407.8986 Tim Wootton – Co-Founder tim@roverparking.com 416.710.7893}

Globenewswire

Food and beverage manufacturers convene session on business competitiveness in Ontario

April 22, 2017April 21, 2017 by The Canadian Press

FOR: FOOD AND BEVERAGE ONTARIO

GUELPH, Ontario, April 21, 2017 (GLOBE NEWSWIRE) — On April 27th, food and beverage manufacturers are meeting to define what is needed to improve the business environment in Ontario. This consultation, hosted by Food and Beverage Ontario, will bring together start-up, small, medium and multi-national businesses from across all segments of the food and beverage sector. FBO will collect input from businesses on their priorities with respect to regulatory reform, r&d and innovation, market and trade development, skills gaps and workforce, environmental sustainability and the next Agricultural Policy Framework (2018 – 2023). The focus is on understanding what steps must be taken to foster a strong business growth environment for Ontario food and beverage manufacturers.

“As a small, family-run company started in 1983 we have experienced first-hand the ups and downs of operating a food business in Ontario,” said Will Rootham of Rootham Gourmet Preserves. “We know that success comes from smartly managing our business in tandem with a supportive economic environment. Connecting with other processor businesses to discuss what we need for success is an important step to communicating those needs to the provincial government. Later this month we will be meeting with our colleagues in the Ontario processing industry and in government to have this important conversation.”

Recent economic analysis completed by Food and Beverage Ontario using the most current 2015 statistics has provided insight on the state of the industry and the economic impact of Ontario’s 3,800 food and beverage manufacturing businesses.

Approximately $71.8 billion in total output, consisting of direct output of $42.0 billion, indirect output of $24.5 billion and induced output of $5.2 billion.
Approximately $28.5 billion in total GDP, consisting of direct GDP of $13.6 billion, indirect GDP of $10.7 billion, and induced GDP of $4.2 billion.
Approximately 387,786 total full time equivalent (FTE) positions, consisting of 139,549 direct FTEs, 174,600 indirect FTEs, and 73,637 induced FTEs.
Approximately $5.6 billion in total federal, provincial, and municipal tax revenue, consisting of direct tax revenue of $2.6 billion, indirect tax revenue of $2.2 billion, and induced tax revenue of $890.0 million.

“Since the previous economic impact study completed by Food and Beverage Ontario in 2012, the sector’s total output, GDP and government tax revenues increased by approximately 3 percent,” said, Norm Beal, CEO of FBO. “I am sorry to say, but this is really lackluster growth given the nominal GDP in Ontario increased 12 percent during the same time period. We are the number one employer in the province so why aren’t we performing better? Processors from across Ontario will be wrestling with this issue on April 27th.”

The announcement of the federal 2017 budget last month did signal a turning point for the food and beverage manufacturing industry nationally with commitments to innovation, discovery science, food industry eligibility as a supercluster, skills initiatives and new investments for food safety.

“There is every reason to be happy with federal budget 2017 and acknowledgement of food and beverage manufacturing as a key growth sector for the country. We have worked hard to reach this level of recognition. It is now incumbent on businesses to step up and identify specific priorities for success with an emphasis on pre-competitive issues that collectively will make our sector a global leader in areas like innovation and skills training,” said Rory McAlpine, Maple Leaf Foods.

Ontario processors are invited to participate in Food and Beverage Ontario’s Consultation for Success on April 27th. To read the pre- consultation paper follow this link and for details on the consultation click here.

This project is funded in part by Growing Forward 2, a federal-provincial-territorial initiative.

About Food and Beverage Ontario

Food and Beverage Ontario is a not-for-profit, leadership organization dedicated to advancing the interests of Ontario’s food and beverage processors. FBO’s focus is on the success, prosperity and growth of the food and beverage processing sector – a $42 billion industry and major contributor to the province’s economy.

FOR FURTHER INFORMATION PLEASE CONTACT:

For media inquiries contact: Isabel Dopta Director of Communications Food and Beverage Ontario idopta@foodandbeverageontario.ca 519.993.1192

INDUSTRY:

Food and Beverage – Food

SUBJECT: CAL

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: For media inquiries contact: Isabel Dopta Director of Communications Food and Beverage Ontario idopta@foodandbeverageontario.ca 519.993.1192}

Globenewswire

How to Increase Your Sales Team's ROPE (Return On Prospecting Effort) – Sandler Training

June 28, 2017April 21, 2017 by EnergyNow Media

Written by Hamish Knox; President of Sandler in Calgary, Canada Managers are rope makers. Their direct reports get to choose to climb that rope or hang themselves with it. Managers make the rope they give their salespeople from onboarding, coaching, mentoring, role play and accountability. I’ve talked to managers who gave their … Read more

Epsilon Completes Rights Offering for $24.5M

April 21, 2017 by The Canadian Press

FOR: EPSILON ENERGY LTD.TSX SYMBOL: EPSDate issue: April 21, 2017Time in: 1:48 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 21, 2017) –
NOT FOR DISTRIBUTION IN THE UNITED STATES OR OVER UNITED STATES NEWS WIRE
SERVICES.
Epsilon Energy Ltd. (“E…

Vital Energy Inc.: Further Details on Pennant Project, S.W. Saskatchewan – Core Project Area

April 21, 2017 by The Canadian Press

FOR: VITAL ENERGY INC.TSX VENTURE SYMBOL: VUXDate issue: April 21, 2017Time in: 1:38 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 21, 2017) – Vital Energy Inc. (“Vital”)
(TSX VENTURE:VUX) announced today, further to its news releases dated Mar…

Chevron loses appeal against $260 million Australia tax bill

April 21, 2017 by The Canadian Press

CANBERRA, Australia — An Australian subsidiary of U.S. energy giant Chevron Corp. lost a court appeal on Friday against a 340 million Australian dollar ($260 million) tax bill in a ruling with ramification for how multinational corporations transfer money.

Three judges of the Australian Federal Court unanimously rejected Chevron Australia’s appeal against tax assessments for five years ending in 2008.

The court found the company had reduced its Australian tax cost through 9 per cent tax-deductible interest payments on a $2.5 billion loan from U.S.-based subsidiary Chevron Texaco Funding Corp., which had borrowed the money at a lower rate.

The Australian Taxation Office welcomed the ruling which it said has direct implications for other cases the office is pursuing regarding loans within multinational corporations.

Australia has some of the world’s toughest rules to ensure it collects the correct amount of tax on profits made in the country, said Treasurer Scott Morrison.

Chevron said it was disappointed and might appeal to the High Court of Australia.

“As recognized by the trial court in the dispute, the financing is a legitimate business arrangement and the parties differ only in their assessments of the appropriate interest rate to apply,” a Chevron statement said.

Grant Wardell-Johnson, a tax partner at KPMG, described the ruling as a “critical case.”

“This is a substantial win for the (Australian Taxation) Commissioner, and many taxpayers will need to review their transfer pricing methodologies,” Wardell-Johnson said.

Taxe authorities have said seven global technology, energy and resources companies will receive a combined bill for outstanding tax of AU$2 billion ($1.5 billion) by the end of June. The companies have not been named.

Rod McGuirk, The Associated Press

NeuLion and Nokia Announce Real Time End-to-End, Live VR Streaming Partnership Enabling Professional 360 VR Production, Delivery

April 21, 2017 by The Canadian Press

FOR: NEULION, INC.

PLAINVIEW, N.Y., April 21, 2017 (GLOBE NEWSWIRE) — NeuLion, Inc. (TSX:NLN), a leading technology product and service provider that specializes in the digital video broadcasting, distribution and monetization of live and on-demand content to Internet-enabled devices, today announced that Nokia’s OZO Live and OZO Reality Platform, together with the NeuLion® Digital Platform, will offer joint customers complete end-to-end production, delivery, monetization and play-back of live and on-demand VR content to enable professional 360 VR streaming and delivery with unprecedented efficiency and quality.

NeuLion and Nokia will offer content owners and content rights holders an end-to-end, jointly integrated platform. This integration will send the single stitched live video feed from OZO Live to the NeuLion Digital Platform, for the live encoding of sports and entertainment. The OZO Reality platform, with the new efficient viewport-adaptive streaming software OZO Deliver and OZO Player SDK, will unlock new high quality experiences for NeuLion customers. The combination of OZO technologies and the NeuLion Digital Platform will enable professional 360 VR streaming and delivery with unprecedented efficiency and quality.

“We’re excited to continue to strengthen our relationship with NeuLion, a company with a reputation for superior technology, quality and service,” said Tarif Sayed, Head of VR Technologies for Nokia. “OZO Live is a real-time 3D 360 stitching software, running on reference hardware that delivers live virtual reality broadcasting at scale. Our OZO Reality platform, which brings together OZO Deliver and OZO Player SDK to enable the delivery of high quality VR experiences, is a great complement to the NeuLion Digital Platform.”

“A clear differentiator for NeuLion, and what we’re recognized for in the marketplace, is our keen focus on the experience we create for our customers as they build their OTT and TV Everywhere services,” said Roy Reichbach, NeuLion’s President and CEO. “With live 360 video and virtual reality going mainstream, it’s mission critical to have an end-to-end platform that includes production and delivery to make it happen. We are excited to be working with Nokia on this new capability.”

The combination of OZO Live and the NeuLion Digital Platform also offers VR content owners monetization features around the production and delivery of their content. VR Content rights holders can monetize content using any combination of business models to unlock VR revenues.

VR Subscription Service
Pay TV Authentication for VR Content
Transactional Services through VR Pay-Per-View
Mid Roll Ad Delivery in VR Content
VR Content Electronic Sell Through via a Purchase Model

The partnership with Nokia also extends into App development. In 2016, NeuLion developed Apps resulted in over 30 million downloads for Apple and Google Play stores. NeuLion App development efforts will also include support for the OZO Player SDK, a full-featured, multi-platform software toolkit that allows for the quick and efficient building and publishing of VR app content.

A PDF accompanying this announcement is available at http://www.globenewswire.com/NewsRoom/AttachmentNg/49107b55-71ed-4d39-9861-3c6cad6b6d69

About NeuLion

NeuLion, Inc. (TSX:NLN) offers solutions that power the highest quality digital experiences for live and on-demand content in up to 4K on any device. Through its end-to-end technology platform, NeuLion enables digital video management, distribution and monetization for content owners worldwide, including the NFL, NBA, World Surf League, Univision Deportes, Euroleague Basketball and others. NeuLion powers the entire video ecosystem for content owners and rights holders, consumer electronic companies, and third party video integrators through its MainConcept business. NeuLion’s robust consumer electronics licensing business enables its customers like Sony, LG, Samsung and others to stream secure, high-quality video seamlessly across their consumer devices. NeuLion is headquartered in Plainview, NY. For more information about NeuLion, visit www.NeuLion.com.

Forward-Looking StatementsCertain statements herein are forward-looking statements and represent NeuLion’s current intentions in respect of future activities. Forward-looking statements can be identified by the use of the words “will,” “expect,” “seek,” “anticipate,” “believe,” “plan,” “estimate,” “expect,” and “intend” and statements that an event or result “may,” “will,” “can,” “should,” “could,” or “might” occur or be achieved and other similar expressions. These statements, in addressing future events and conditions, involve inherent risks and uncertainties. Although the forward-looking statements contained in this release are based upon what management believes to be reasonable assumptions, NeuLion cannot assure readers that actual results will be consistent with these forward-looking statements. These forward-looking statements are made as of the date of this release and NeuLion assumes no obligation to update or revise them to reflect new events or circumstances, except as required by law. Many factors could cause NeuLion’s actual results, performance or achievements to be materially different from any future results, performance or achievements that may be expressed or implied by such forward-looking statements, including: our ability to derive anticipated benefits from the acquisitions of DivX and Saffron Digital; our ability to realize some or all of the anticipated benefits of our partnerships; general economic and market segment conditions; our customers’ subscriber levels and financial health; our ability to pursue and consummate acquisitions in a timely manner; our continued relationships with our customers; our ability to negotiate favorable terms for contract renewals; competitor activity; product capability and acceptance rates; technology changes; regulatory changes; foreign exchange risk; interest rate risk; and credit risk. These factors should be considered carefully and readers should not place undue reliance on the forward-looking statements. A more detailed assessment of the risks that could cause actual results to materially differ from current expectations is contained in the “Risk Factors” section of NeuLion’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016, which is available on www.sec.gov and filed on www.sedar.com.

FOR FURTHER INFORMATION PLEASE CONTACT:

Contact Information Press Contact: Chris Wagner | chris.wagner@neulion.com | +1 858 336 8728 Investor Relations Contact: Rob Kelly | rob.kelly@loderockadvisors.com | +1 416 992 4539

INDUSTRY:

Computers and Software – Hardware

SUBJECT: MISPRT

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Contact Information Press Contact: Chris Wagner | chris.wagner@neulion.com | +1 858 336 8728 Investor Relations Contact: Rob Kelly | rob.kelly@loderockadvisors.com | +1 416 992 4539}

Globenewswire

Hydrogenics Selected as Technology Provider for SunLine Transit Agency

April 21, 2017 by The Canadian Press

FOR: HYDROGENICS CORPORATION

MISSISSAUGA, Ontario, April 21, 2017 (GLOBE NEWSWIRE) — Hydrogenics Corporation (NASDAQ:HYGS) (TSX:HYG) (“Hydrogenics” or “the Company”), a leading developer and manufacturer of hydrogen generation and hydrogen-based fuel cell modules, today announced that it has been selected to be the technology provider for the SunLine Transit Agency, covering heavy duty fuel cell power modules and PEM HyLyzer™ electrolysis equipment, to enable zero-emission public transit. Funded by a major grant award from California Climate Investments and the California Air Resources Board (“CARB”), Hydrogenics will supply SunLine with five CelerityPlus™ power modules to be integrated into New Flyer fuel cell buses. Hydrogenics will also upgrade SunLine’s heavy duty fueling station with a new 1.5 megawatt PEM electrolyzer for onsite hydrogen fuel generation – making it the largest renewable hydrogen fueling facility in the United States. The station will produce up to 400 kilograms of hydrogen daily and be capable of fueling 15 buses per day.

“As the only hydrogen technology company that can offer both fuel cell power systems and clean onsite hydrogen generation, we are pleased to bring our advanced technology to this state-of-the-art project in California,” stated Daryl Wilson, President and CEO of Hydrogenics. “SunLine has been at the forefront of clean energy transportation in the region, and we look forward to being a part of implementing this zero-emission vehicle initiative.”

This is the first bundled hydrogen fleet and fuel project secured by a transit agency where funding has been received for both the heavy duty fuel cells and infrastructure for onsite renewable hydrogen generation supplied by the same technology provider. Successful deployment of this project will help remove barriers due to lack of hydrogen infrastructure and accelerate mass adoption of fuel cell buses within the transit industry.

The SunLine Fuel Cell Buses and Hydrogen Onsite Generation Refueling Station Pilot Commercial Deployment Project is part of California Climate Investments, a statewide program that puts billions of cap-and-trade dollars to work reducing greenhouse gas emissions, strengthening the economy and improving public health and the environment—particularly in disadvantaged communities. The cap-and-trade program also creates a financial incentive for industries to invest in clean technologies and develop innovative ways to reduce pollution. California Climate Investment projects include affordable housing, renewable energy, public transportation, zero-emission vehicles, environmental restoration, more sustainable agriculture, recycling and much more. At least 35 percent of these investments are made in disadvantaged and low-income communities. For more information, visit California Climate Investments (https://arb.ca.gov/caclimateinvestments.)

About HydrogenicsHydrogenics Corporation is a world leader in engineering and building the technologies required to enable the acceleration of a global power shift. Headquartered in Mississauga, Ontario, Hydrogenics provides hydrogen generation, energy storage and hydrogen power modules to its customers and partners around the world. Hydrogenics has manufacturing sites in Germany, Belgium and Canada and service centers in Russia, Europe, the US and Canada.

Forward-looking StatementsThis release contains forward-looking statements within the meaning of the “safe harbor” provisions of the U.S. Private Securities Litigation Reform Act of 1995, and under applicable Canadian securities law. These statements are based on management’s current expectations and actual results may differ from these forward-looking statements due to numerous factors, including: our inability to increase our revenues or raise additional funding to continue operations, execute our business plan, or to grow our business; inability to address a slow return to economic growth, and its impact on our business, results of operations and consolidated financial condition; our limited operating history; inability to implement our business strategy; fluctuations in our quarterly results; failure to maintain our customer base that generates the majority of our revenues; currency fluctuations; failure to maintain sufficient insurance coverage; changes in value of our goodwill; failure of a significant market to develop for our products; failure of hydrogen being readily available on a cost-effective basis; changes in government policies and regulations; failure of uniform codes and standards for hydrogen fuelled vehicles and related infrastructure to develop; liability for environmental damages resulting from our research, development or manufacturing operations; failure to compete with other developers and manufacturers of products in our industry; failure to compete with developers and manufacturers of traditional and alternative technologies; failure to develop partnerships with original equipment manufacturers, governments, systems integrators and other third parties; inability to obtain sufficient materials and components for our products from suppliers; failure to manage expansion of our operations; failure to manage foreign sales and operations; failure to recruit, train and retain key management personnel; inability to integrate acquisitions; failure to develop adequate manufacturing processes and capabilities; failure to complete the development of commercially viable products; failure to produce cost-competitive products; failure or delay in field testing of our products; failure to produce products free of defects or errors; inability to adapt to technological advances or new codes and standards; failure to protect our intellectual property; our involvement in intellectual property litigation; exposure to product liability claims; failure to meet rules regarding passive foreign investment companies; actions of our significant and principal shareholders; dilution as a result of significant issuances of our common shares and preferred shares; inability of US investors to enforce US civil liability judgments against us; volatility of our common share price; and dilution as a result of the exercise of options; and failure to meet continued listing requirements of Nasdaq. Readers should not place undue reliance on Hydrogenics’ forward-looking statements. Investors are encouraged to review the section captioned “Risk Factors” in Hydrogenics’ regulatory filings with the Canadian securities regulatory authorities and the US Securities and Exchange Commission for a more complete discussion of factors that could affect Hydrogenics’ future performance. Furthermore, the forward-looking statements contained herein are made as of the date of this release, and Hydrogenics undertakes no obligations to revise or update any forward-looking statements in order to reflect events or circumstances that may arise after the date of this release, unless otherwise required by law. The forward-looking statements contained in this release are expressly qualified by this.

FOR FURTHER INFORMATION PLEASE CONTACT:

For further information, contact: Bob Motz, Chief Financial Officer Hydrogenics Corporation (905) 361-3660 investors@hydrogenics.com Chris Witty Hydrogenics Investor Relations (646) 438-9385 cwitty@darrowir.com

INDUSTRY:

Manufacturing and Production – Machinery and Tools

SUBJECT: PDT

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: For further information, contact: Bob Motz, Chief Financial Officer Hydrogenics Corporation (905) 361-3660 investors@hydrogenics.com Chris Witty Hydrogenics Investor Relations (646) 438-9385 cwitty@darrowir.com}

Globenewswire

Apricus Biosciences Announces Pricing of $7.0 Million Public Offering

April 21, 2017 by The Canadian Press

FOR: APRICUS BIOSCIENCES

SAN DIEGO, April 21, 2017 (GLOBE NEWSWIRE) — Apricus Biosciences, Inc. (Nasdaq:APRI), a biopharmaceutical company advancing innovative medicines in urology and rheumatology, today announced the pricing of an underwritten public offering of an aggregate of 5,030,000 units, with each unit consisting of one share of Apricus common stock and one warrant to purchase 0.75 of a share of common stock, at a public offering price of $1.40 per unit. The shares of common stock and warrants are immediately separable and will be issued separately in this offering. Apricus’ gross proceeds from this offering are expected to be approximately $7.0 million, before deducting underwriting discounts and commissions and other estimated offering expenses, and excluding any proceeds Apricus may receive upon exercise of the warrants to be issued in this offering. The offering is expected to close on or about April 26, 2017, subject to the satisfaction of customary closing conditions.

Rodman & Renshaw, a unit of H.C. Wainwright & Co. is acting as sole book-running manager for the offering.

The warrants will become exercisable only following Apricus’ announcement that it has received shareholder approval of an amendment to its Amended and Restated Articles of Incorporation to increase the number of authorized shares of common stock to a total of 30,000,000 shares and such amendment has become effective. The warrants will expire five years from the date they are first exercisable, and have an exercise price of $1.55 per share.

Apricus intends to use the net proceeds of this offering to fund activities in connection with its planned re-submission of its NDA for Vitaros to the FDA and for general corporate purposes and working capital.

The securities described above are being issued and sold pursuant to an effective registration statement on Form S-1, which was previously filed with the Securities and Exchange Committee (the “SEC”) and declared effective on April 20, 2017 (File No. 333-217036). The offering of these securities will be made only by means of a prospectus. Copies of the final prospectus, when available, may be obtained at the SEC’s website located at http://www.sec.gov and may also be obtained by calling H.C. Wainwright & Co., LLC at (646) 975-6996 or requesting a copy by email at placements@hcwco.com.

This press release shall not constitute an offer to sell or the solicitation of an offer to buy these securities, nor shall there be any sale of these securities in any state or other jurisdiction in which such offer, solicitation or sale would be unlawful prior to the registration or qualification under the securities laws of any such state or other jurisdiction.

About Apricus Biosciences, Inc.

Apricus Biosciences, Inc. (APRI) is a biopharmaceutical company advancing innovative medicines in urology and rheumatology. Apricus has two product candidates currently in development. Vitaros is a product candidate in the United States for the treatment of erectile dysfunction, which is in-licensed from Warner Chilcott Company, Inc., now a subsidiary of Allergan plc (Allergan). RayVa is our product candidate in Phase 2 development for the treatment of the circulatory disorder Raynaud’s phenomenon, secondary to scleroderma, for which Apricus owns worldwide rights.

Vitaros™ is Apricus’ trademark in the United States, which is pending registration and subject to the agreement with Allergan. Vitaros® is a registered trademark of Ferring B.V. in certain countries outside of the United States. RayVa™ is Apricus’ trademark, which is registered in certain countries throughout the world and pending registration in the United States.

Forward Looking Statements

Certain statements contained in this news release, other than statements of fact that are independently verifiable at the date hereof, may constitute forward-looking information and forward-looking statements (collectively “forward-looking statements” within the meaning of applicable securities laws). Such statements, based as they are on the current expectations of management of Apricus and upon what management believes to be reasonable assumptions based on information currently available to it, inherently involve numerous risks and uncertainties, known and unknown, many of which are beyond Apricus’ control. Such statements can usually be identified by the use of words such as “may,” “would,” “believe,” “intend,” “plan,” “anticipate,” or “estimate” and other similar terminology, or state that certain actions, events or results “may” or “would” be taken, occur or be achieved. Forward-looking statements in this release include, but are not limited to, statements related to the expected completion, timing and size of the public offering of units and Apricus’ expected used of the proceeds from the offering. Whether actual results and developments will conform with our expectations and predictions is subject to a number of risks, assumptions and uncertainties, many of which are beyond our control, and the effects of which can be difficult to predict. These risks include those associated with market risks and uncertainties and the satisfaction of customary closing conditions for an offering of securities, and other risks described in Apricus’ filings with the SEC. In evaluating any forward-looking statements in this release, Apricus cautions readers not to place undue reliance on any forward-looking statements. Unless otherwise required by applicable securities laws, Apricus does not intend, nor does it undertake any obligation, to update or revise any forward-looking statements contained in this news release to reflect subsequent information, events, results or circumstances or otherwise.

FOR FURTHER INFORMATION PLEASE CONTACT:

CONTACT: Matthew Beck mbeck@troutgroup.com The Trout Group (646) 378-2933

INDUSTRY:

Pharmaceuticals and Biotech – Biotech

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: CONTACT: Matthew Beck mbeck@troutgroup.com The Trout Group (646) 378-2933}

Globenewswire

Vital Energy Inc.: Pennant Project, S.W. Saskatchewan – Core Project Area

April 21, 2017 by The Canadian Press

FOR: VITAL ENERGY INC.TSX VENTURE SYMBOL: VUXDate issue: April 21, 2017Time in: 9:25 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 21, 2017) – Vital Energy Inc. (“Vital”)
(TSX VENTURE:VUX) announces that, further to its news release dated March…

Condor Provides an Operations Update for Turkey

April 21, 2017 by The Canadian Press

FOR: CONDOR PETROLEUM INC.TSX Symbol: CPIDate issue: April 21, 2017Time in: 9:00 AM eAttention:
CALGARY, AB –(Marketwired – April 21, 2017) – Condor Petroleum Inc.
(“Condor” or the “Company”) (TSX: CPI) is pleased to provide an operations
update for …

Enbridge Inc. to Hold Annual Meeting of Shareholders on May 11, 2017

April 21, 2017 by The Canadian Press

FOR: ENBRIDGE INC.TSX SYMBOL: ENBNYSE SYMBOL: ENBDate issue: April 21, 2017Time in: 9:00 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 21, 2017) – Enbridge Inc.
(TSX:ENB)(NYSE:ENB) will hold its Annual Meeting of Shareholders in Calgary,
Albert…

Enbridge Income Fund Holdings Inc. to Hold Annual Meeting of Shareholders on May 11, 2017

April 21, 2017 by The Canadian Press

FOR: ENBRIDGE INCOME FUND HOLDINGS INC.TSX SYMBOL: ENFDate issue: April 21, 2017Time in: 9:00 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 21, 2017) – Enbridge Income Fund
Holdings Inc. (TSX:ENF) will hold its Annual Meeting of Shareholders in…

Enbridge Inc. to Host a Joint Webcast with Enbridge Income Fund Holdings Inc., Enbridge Energy Partners, L.P. and Spectra Energy Partners, LP to Discuss First Quarter Financial Results on May 11

April 21, 2017 by The Canadian Press

FOR: ENBRIDGE INCOME FUND HOLDINGS INC.TSX SYMBOL: ENFDate issue: April 21, 2017Time in: 9:00 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 21, 2017) – Enbridge Inc.
(TSX:ENB)(NYSE:ENB) (Enbridge) will host a joint conference call and webcast
w…

Delek Group Ltd.’s Offer to acquire Ithaca Energy Inc. common shares extended for mandatory extension period to May 3, 2017

April 21, 2017 by The Canadian Press

FOR: DELEK GROUP LTD.
Date issue: April 21, 2017Time in: 7:00 AM eAttention:
TEL AVIV, ISRAEL–(Marketwired – April 21, 2017) – Delek Group Ltd. (“Delek”),
and its wholly-owned subsidiary, DKL Investments Limited (the “Offeror”), today
announced that t…

Ithaca Energy Inc: Bond Consents Update

April 20, 2017 by The Canadian Press

FOR: ITHACA ENERGY INCTSX SYMBOL: IAELSE SYMBOL: IAEDate issue: April 21, 2017Time in: 2:27 AM eAttention:
ABERDEEN, SCOTLAND–(Marketwired – April 20, 2017) – Ithaca Energy Inc (TSX:
IAE) (LSE: IAE)
TSX: IAE, LSE AIM: IAE
THIS ANNOUNCEMENT CONTAINS IN…

Ithaca Energy Inc.: Delek Takeover Conditions Satisfied

April 20, 2017 by The Canadian Press

FOR: ITHACA ENERGY INCTSX SYMBOL: IAEAIM SYMBOL: IAEDate issue: April 21, 2017Time in: 2:21 AM eAttention:
ABERDEEN, SCOTLAND–(Marketwired – April 20, 2017) – Ithaca Energy Inc. (TSX:
IAE) (AIM: IAE)
(TSX: IAE; LSE: IAE)
NOT FOR RELEASE, PUBLICATION O…

MHRMI Meets with Global Affairs Canada – Calls on Foreign Minister to Retract Macedonia Statement, Support Macedonia’s Sovereign

April 20, 2017 by The Canadian Press

FOR: MACEDONIAN HUMAN RIGHTS MOVEMENT INTERNATIONAL

TORONTO, April 20, 2017 (GLOBE NEWSWIRE) — Macedonian Human Rights Movement International President, Bill Nicholov, continued his ongoing meetings with senior officials from Global Affairs Canada and called for Minister of Foreign Affairs, Chrystia Freeland, to immediately retract her contradictory statement on Macedonia, and show support for Macedonia’s struggle against foreign interference.

In a statement issued about Ukraine, Minister Freeland said, “Canada is unwavering in its support to Ukraine, both in helping to preserve and protect Ukraine’s sovereignty, and in providing assistance to Ukraine to implement key reforms.” An identical statement could have been issued about Macedonia, but Minister Freeland chose to undermine Macedonia’s sovereignty by calling for a mandate to be given to a coalition whose public goal is to change Macedonia’s name, identity, flag, anthem and coat of arms, and which threatens Macedonia’s territorial integrity. In addition to campaigning on this platform, the anti-Macedonia coalition recently formally presented it in parliament. Macedonians have been protesting, en masse, against this platform and in defence of their country.

To indulge Minister Freeland’s apparent reason for this statement, to be “…in compliance with the constitution”, the Macedonian constitution clearly states that a mandate cannot be given to a coalition that threatens the “unitary character of Macedonia”. Understandably so. To ignore the foreign interference, turmoil and mass protests in Macedonia shows a complete lack of judgement on Minister Freeland’s part and, at best, shows that she is out of touch with the current situation and, at worst, is complicit in supporting foreign interventionism in Macedonia.

The United States, some European Union countries, and sadly, Canada, have turned the Macedonian people’s defence of their country and ethnic origin into a “left vs. right” issue. This is not a matter of political ideology, but a non-partisan defence against a US-backed platform, drafted in Albania under Albanian Prime Minister Edi Rama’s “guidance”, aimed at redefining Macedonians’ ethnicity and sovereignty. Canada used to stand up against such attacks, now it participates in them. Minister Freeland’s remarks go against Canada’s long-standing policy against foreign interventionism, and is an affront to Canadian values of self-determination and human rights.

MHRMI called for Minister Freeland to explain her reasons for issuing this statement, and to announce when a retraction can be expected. Staying silent on this issue is not an option, especially when her statement is fueling ethnic tensions in Macedonia. This is not the Canada that we know.

— Macedonian Human Rights Movement International (MHRMI) has been active on human and national rights issues for Macedonians and other oppressed peoples since 1986. For more information: 1-416-850-7125, info@mhrmi.org, www.mhrmi.org, twitter.com/mhrmi, facebook.com/mhrmi, mhrmi.org/OurNameIsMacedonia

FOR FURTHER INFORMATION PLEASE CONTACT:

INDUSTRY:

Professional Services – Other Professional Services

SUBJECT: PLT

NEWS RELEASE TRANSMITTED BY Globe Newswire

^Information:

Globenewswire

Uranium Resources to Present at Planet MicroCap Showcase

April 20, 2017 by The Canadian Press

FOR: URANIUM RESOURCES

CENTENNIAL, Colo., April 20, 2017 (GLOBE NEWSWIRE) — Uranium Resources, Inc. (Nasdaq:URRE) (ASX:URI), an energy metals exploration and development company, announced that President and CEO Christopher M. Jones will provide a business update in a presentation at the Planet MicroCap Showcase conference at 1:30 p.m. PDT on Thursday, April 27, 2017.

Mr. Jones will also meet with investors during the conference. A live webcast and a PDF of the presentation will be available under the Investors section of www.uraniumresources.com.

The Planet MicroCap Showcase is a conference organized by StockNewsNow.com that brings together promising companies with microcap investors, fund managers and newsletter writers over April 26-28, 2017 at Planet Hollywood Resort & Casino in Las Vegas. Investors interested in attending the Company’s presentation and the conference should contact the conference organizer, Robert Kraft at rkraft@snnwire.com or visit www.planetmicrocapshowcase.com for further information.

About Uranium Resources (URI)

URI is focused on expanding its energy metals strategy, which includes developing its new lithium business while maintaining optionality on the future rising uranium price. The Company has developed a dominant land position in two prospective lithium brine basins in Nevada and Utah in preparation for exploration and potential development of any lithium resources that may be discovered there. In addition, URI remains focused on advancing the Temrezli in-situ recovery (ISR) uranium project in Central Turkey when uranium prices permit economic development of this project. URI controls extensive exploration properties in Turkey under eight exploration and operating licenses covering approximately 39,000 acres (over 16,000 ha) with numerous exploration targets, including the potential satellite Sefaatli Project, which is 30 miles (48 km) southwest of the Temrezli Project. In Texas, the Company has two licensed and currently idled uranium processing facilities and approximately 11,000 acres (4,400 ha) of prospective ISR uranium projects. In New Mexico, the Company controls mineral rights encompassing approximately 186,000 acres (75,300 ha) in the prolific Grants Mineral Belt, which is one of the largest concentrations of sandstone-hosted uranium deposits in the world. Incorporated in 1977, URI also owns an extensive information database of historic drill hole logs, assay certificates, maps and technical reports for uranium properties located in the Western United States.

FOR FURTHER INFORMATION PLEASE CONTACT:

Uranium Resources Contacts Christopher M. Jones, President and CEO 303.531.0472 Email: Info@uraniumresources.com Website: www.uraniumresources.com Jeff Vigil, VP Finance and CFO 303.531.0473

INDUSTRY:

Manufacturing and Production – Mining and Metals

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Uranium Resources Contacts Christopher M. Jones, President and CEO 303.531.0472 Email: Info@uraniumresources.com Website: www.uraniumresources.com Jeff Vigil, VP Finance and CFO 303.531.0473}

Globenewswire

PRGX Global, Inc. to Hold First Quarter 2017 Financial Results Call on April 26, 2017

April 20, 2017 by The Canadian Press

FOR: PRGX GLOBAL, INC.

ATLANTA, April 20, 2017 (GLOBE NEWSWIRE) — PRGX Global, Inc. (Nasdaq:PRGX), a global leader in Recovery Audit and Spend Analytics services, today announced that the company will release its financial results for the first quarter 2017 at approximately 7:00 AM (Eastern time) on Wednesday, April 26, 2017. Management will hold a conference call later that morning at 8:30 AM (Eastern time) to discuss those results.

To access the conference call, listeners in the U.S. and Canada should dial (877) 755-7423 at least 5 minutes prior to the start of the conference. Listeners outside the U.S. and Canada should dial (678) 894-3069. To be admitted to the call, listeners should use passcode 10006589.

This teleconference will also be audiocast on the Internet at www.prgx.com (click on “Events & Presentations” under “Investors”). A replay of the audiocast will be available at the same location beginning approximately two hours after the conclusion of the live audiocast, extending through June 30, 2017. Please note that the Internet audiocast is “listen-only.” Microsoft Windows Media Player is required to access the live audiocast and the replay and can be downloaded from www.microsoft.com/windows/mediaplayer.

About PRGX Global, Inc.

PRGX Global, Inc. is a global leader in Recovery Audit and Spend Analytics services. With over 1,400 employees, the Company serves clients in more than 30 countries and provides its services to 75% of the top 20 global retailers and over 20% of the top 50 companies in the Fortune 500. PRGX delivers more than $1 billion in cash flow improvement for its clients each year. The creator of the recovery audit industry more than 40 years ago, PRGX continues to innovate through technology and expanded service offerings. In addition to Recovery Audit, the Company provides Contract Compliance, Spend Analytics and Supplier Information Management services to improve clients’ financial performance and manage risk. For additional information on PRGX, please visit www.prgx.com

This news release was distributed by GlobeNewswire, www.globenewswire.com

FOR FURTHER INFORMATION PLEASE CONTACT:

CONTACT: PRGX Global, Inc. investor-relations@prgx.com Phone: 770-779-3011

INDUSTRY:

Computers and Software – Software

SUBJECT: CAL

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: CONTACT: PRGX Global, Inc. investor-relations@prgx.com Phone: 770-779-3011}

Globenewswire

Brookfield Property Partners Enters Into Definitive Agreement With Brookfield Canada Office Properties for Going Private Transac

April 20, 2017 by The Canadian Press

FOR: BROOKFIELD PROPERTY PARTNERS L.P.

BROOKFIELD NEWS, April 20, 2017 (GLOBE NEWSWIRE) — Brookfield Property Partners L.P. (NYSE:BPY) (TSX:BPY.UN) (“BPY”) announced today that it has entered into a definitive agreement with Brookfield Canada Office Properties (TSX:BOX.UN) (NYSE:BOXC) (“BOX”) pursuant to which BPY would effectively acquire the approximately 17% equity interest in BOX that it or its subsidiaries do not own (approximately 15.9 million units) for $32.50 cash per unit. BOX unitholders will be entitled to receive monthly distributions through to closing (pro-rated if required) at the current rate of $0.1092 per unit as declared by the BOX Board of Trustees in the ordinary course.

“We are pleased to have entered into an agreement with BOX to consolidate our North American office operations while providing liquidity to BOX unitholders at a significant premium to recent public market pricing,” said Brian Kingston, CEO of Brookfield Property Group.

The going private transaction is to be effected through a definitive redemption agreement pursuant to which BOX will redeem all of its issued and outstanding units not already owned by BPY and its subsidiaries. Under the terms of the agreement, unitholders of BOX will receive $32.50 in cash per unit, which is $2.40, or 8% more than BPY’s initial January 23, 2017 offer to privatize BOX for $30.10 per unit. The $32.50 per unit consideration represents a premium of 23% to the 30-day volume-weighted average price of BOX units on the Toronto Stock Exchange and 22% to the 30-day volume-weighted average price of BOX units on the New York Stock Exchange for the period ended January 20, 2017 (being the last trading day prior to the announcement of BPY’s privatization proposal). The transaction provides total consideration to minority unitholders of BOX of approximately $515.7 million.

The BOX Board of Trustees approved the redemption agreement following the report and favourable recommendation of its Special Committee of independent trustees established to review and consider the transaction. The BOX Board of Trustees intends to unanimously recommend that unitholders of BOX approve the redemption.

In coming to this conclusion, the BOX Board of Trustees determined that the redemption is in the best interests of BOX and is substantively and procedurally fair to its unaffiliated unitholders. Greenhill & Co., the independent valuator and financial adviser to the Special Committee, concluded that, as of April 20, 2017, based upon and subject to the analyses, assumptions, qualifications and limitations set forth in its valuation and fairness opinion, in addition to other factors that it considered relevant, the consideration being offered pursuant to the redemption to unitholders of BOX other than BPY and its subsidiaries was fair, from a financial point of view, to such unitholders and that the fair market value of a unit of BOX was in the range of $31.50 to $34.50. A copy of the Greenhill & Co. valuation and fairness opinion, the factors considered by the Special Committee and BOX’s Board of Trustees and other relevant background information will be included in the management information circular that will be sent to BOX unitholders in connection with the annual and special meeting scheduled (the “Meeting”) to be called to consider the redemption.

The implementation of the redemption is subject to the approval of at least two-thirds of the votes cast at the Meeting by BOX unitholders present in person or by proxy and by a majority of the votes cast by BOX unitholders other than BPY and its subsidiaries. Completion of the redemption is also subject to certain customary conditions.

Unitholders holding approximately 3.52 million units of BOX, representing approximately 22% of the unaffiliated BOX units, including Morgan Stanley Investment Management, who holds approximately 1.4 million units of BOX on behalf of certain client accounts, support the proposal and have agreed, subject to certain conditions, to vote the units of BOX they hold in favor of the transaction.

The transaction is structured as a redemption of units by BOX. As a result, a unitholder who is a resident of Canada for Canadian federal income tax purposes generally will realize a capital gain (or a capital loss) to the extent that such unitholder’s proceeds of disposition, net of any reasonable costs of disposition, exceed (or are exceeded by) the adjusted cost base of the units. Unitholders who are not residents of Canada generally will not be subject to Canadian federal income tax in respect of capital gains realized on a disposition of their units but will be subject to Canadian withholding tax at source of 15% on the full amount of the redemption proceeds. As a result, non-resident unitholders may prefer to sell their units in the public markets with a settlement date that is prior to the completion of the transaction. A unitholder who is taxable in the United States and who exchanges units for cash pursuant to the transaction generally is expected to recognize taxable gain (or loss) for U.S. federal income tax purposes measured by the difference between the amount realized and such unitholder’s adjusted tax basis in such units immediately prior to the exchange. It is strongly suggested that unitholders consult their tax advisors and read carefully the tax disclosure section of the management information circular relating to the transaction when it is available.

This press release is neither an offer to purchase nor a solicitation of an offer to sell securities.

Brookfield Property Partners

Brookfield Property Partners is one of the world’s largest commercial real estate companies, with approximately $65 billion in total assets. We are leading owners, operators and investors in commercial property assets, with a diversified portfolio that includes 142 premier office properties and 127 best-in-class retail malls around the world. We also hold interests in multifamily, triple net lease, industrial, hospitality, self-storage and student housing assets. Brookfield Property Partners is listed on the New York and Toronto stock exchanges. Further information is available at bpy.brookfield.com. Important information may be disseminated exclusively via the website; investors should consult the site to access this information.

Brookfield Property Partners is the flagship listed real estate company of Brookfield Asset Management, a leading global alternative asset manager with approximately $250 billion in assets under management.

Forward-Looking Statements

This press release contains “forward-looking information” within the meaning of Canadian provincial securities laws and applicable regulations and “forward-looking statements” within the meaning of “safe harbor” provisions of the United States Private Securities Litigation Reform Act of 1995. Forward-looking statements include statements that are predictive in nature, depend upon or refer to future events or conditions, include statements regarding our operations, business, financial condition, expected financial results, performance, prospects, opportunities, priorities, targets, goals, ongoing objectives, strategies and outlook, as well as the outlook for North American and international economies for the current fiscal year and subsequent periods, and include words such as “expects,” “anticipates,” “plans,” “believes,” “estimates,” “seeks,” “intends,” “targets,” “projects,” “forecasts,” “likely,”, or negative versions thereof and other similar expressions, or future or conditional verbs such as “may,” “will,” “should,” “would” and “could.”

Although we believe that our anticipated future results, performance or achievements expressed or implied by the forward-looking statements and information are based upon reasonable assumptions and expectations, the reader should not place undue reliance on forward-looking statements and information because they involve known and unknown risks, uncertainties and other factors, many of which are beyond our control, which may cause our actual results, performance or achievements to differ materially from anticipated future results, performance or achievement expressed or implied by such forward-looking statements and information.

Factors that could cause actual results to differ materially from those contemplated or implied by forward-looking statements include, but are not limited to: the successful completion of the redemption by BOX of the units not owned by BPY and its subsidiaries; risks incidental to the ownership and operation of real estate properties including local real estate conditions; the impact or unanticipated impact of general economic, political and market factors in the countries in which we do business; the ability to enter into new leases or renew leases on favorable terms; business competition; dependence on tenants’ financial condition; the use of debt to finance our business; the behavior of financial markets, including fluctuations in interest and foreign exchanges rates; uncertainties of real estate development or redevelopment; global equity and capital markets and the availability of equity and debt financing and refinancing within these markets; risks relating to our insurance coverage; the possible impact of international conflicts and other developments including terrorist acts; potential environmental liabilities; changes in tax laws and other tax related risks; dependence on management personnel; illiquidity of investments; the ability to complete and effectively integrate acquisitions into existing operations and the ability to attain expected benefits therefrom; operational and reputational risks; catastrophic events, such as earthquakes and hurricanes; and other risks and factors detailed from time to time in our documents filed with the securities regulators in Canada and the United States.

We caution that the foregoing list of important factors that may affect future results is not exhaustive. When relying on our forward-looking statements or information, investors and others should carefully consider the foregoing factors and other uncertainties and potential events. Except as required by law, we undertake no obligation to publicly update or revise any forward-looking statements or information, whether written or oral, that may be as a result of new information, future events or otherwise.

FOR FURTHER INFORMATION PLEASE CONTACT:

Contact: Matthew Cherry Senior Vice President, Investor Relations and Communications Tel: (212) 417-7488 Email: matthew.cherry@brookfield.com

INDUSTRY:

Financial Services – Commercial and Investment Banking

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Contact: Matthew Cherry Senior Vice President, Investor Relations and Communications Tel: (212) 417-7488 Email: matthew.cherry@brookfield.com}

Globenewswire

Brookfield Canada Office Properties Enters Into Definitive Agreement With Brookfield Property Partners for Going Private Transac

April 20, 2017 by The Canadian Press

FOR: BROOKFIELD CANADA OFFICE PROPERTIES

BROOKFIELD NEWS, April 20, 2017 (GLOBE NEWSWIRE) — Brookfield Canada Office Properties (TSX:BOX.UN) (NYSE:BOXC) (“BOX”) announced today that it has entered into a definitive agreement with Brookfield Property Partners L.P. (NYSE:BPY) (TSX:BPY.UN) (“BPY”) pursuant to which BPY would effectively acquire the approximately 17% equity interest in BOX that it or its subsidiaries do not own (approximately 15.9 million units) for $32.50 cash per unit. BOX unitholders will be entitled to receive monthly distributions through to closing (pro-rated if required) at the current rate of $0.1092 per unit as declared by the BOX Board of Trustees in the ordinary course.

“We are pleased to have come to terms on a transaction that has the full support of the BOX Board of Trustees,” said, Paul McFarlane, the Chairman of the Special Committee of the BOX Board of Trustees. “We believe that the transaction offers strong value for BOX unitholders, and we look forward to working towards its successful completion.”

The going private transaction is to be effected through a definitive redemption agreement pursuant to which BOX will redeem all of its issued and outstanding units not already owned by BPY and its subsidiaries. Under the terms of the agreement, unitholders of BOX will receive $32.50 in cash per unit, which is $2.40 more than BPY’s initial January 23, 2017 proposal to privatize BOX for $30.10 per unit. The $32.50 per unit consideration represents a premium of 23% to the 30-day volume-weighted average price of BOX units on the Toronto Stock Exchange and 22% to the 30-day volume-weighted average price of BOX units on the New York Stock Exchange for the period ended January 20, 2017 (being the last trading day prior to the announcement of BPY’s privatization proposal). The transaction provides total consideration to minority unitholders of BOX of approximately $515.7 million. The BOX Board of Trustees approved the redemption agreement following the report and favourable recommendation of its Special Committee of independent trustees established to review and consider the transaction. The BOX Board of Trustees intends to unanimously recommend that unitholders of BOX approve the redemption.

The transaction is structured as a redemption of units by BOX. As a result, a unitholder who is a resident of Canada for Canadian federal income tax purposes generally will realize a capital gain (or a capital loss) to the extent that such unitholder’s proceeds of disposition, net of any reasonable costs of disposition, exceed (or are exceeded by) the adjusted cost base of the units. Unitholders who are not residents of Canada generally will not be subject to Canadian federal income tax in respect of capital gains realized on disposition of their units, but will be subject to Canadian withholding tax at source of 15% on the full amount of the redemption proceeds. As a result, non-resident unitholders may prefer to sell their units in the public markets with a settlement date that is prior to the completion of the transaction. A unitholder who is taxable in the United States and who exchanges units for cash pursuant to the transaction generally is expected to recognize taxable gain (or loss) for U.S. federal income tax purposes measured by the difference between the amount realized and such unitholder’s adjusted tax basis in such units immediately prior to the exchange. It is strongly suggested that unitholders consult their tax advisors and read carefully the tax disclosure section of the management information circular relating to the transaction when it is available.

This press release is neither an offer to purchase nor a solicitation of an offer to sell securities.

About Brookfield Canada Office PropertiesBrookfield Canada Office Properties is Canada’s preeminent Real Estate Investment Trust (REIT). Our portfolio is comprised of 26 premier office properties totaling 20 million square feet in the downtown cores of Toronto, Calgary, and Ottawa, in addition to a development site in Calgary. Our landmark assets include Brookfield Place and First Canadian Place in Toronto, and Bankers Hall in Calgary. Further information is available at www.brookfieldcanadareit.com. Important information may be disseminated exclusively via the website; investors should consult the site to access this information.

Brookfield Canada Office Properties is the flagship Canadian REIT of Brookfield Asset Management, a leading global alternative asset manager with approximately $250 billion in assets under management. For more information, go to www.brookfield.com.

Forward-Looking Statements

This news release contains “forward-looking information” within the meaning of Canadian provincial securities laws and applicable regulations and “forward-looking statements” within the meaning of “safe harbor” provisions of the United States Private Securities Litigation Reform Act of 1995. Forward-looking statements include statements that are predictive in nature, depend upon or refer to future events or conditions, include statements regarding the Trust’s operations, business, financial condition, expected financial results, performance, prospects, opportunities, priorities, targets, goals, ongoing objectives, strategies and outlook, as well as the outlook for the Canadian economy for the current fiscal year and subsequent periods, and include words such as “expects,” “anticipates,” “plans,” “believes,” “estimates,” “seeks,” “intends,” “targets,” “projects,” “forecasts,” “likely,” or negative versions thereof and other similar expressions, or future or conditional verbs such as “may,” “will,” “should,” “would” and “could.”

Although the Trust believes that our anticipated future results, performance or achievements expressed or implied by the forward-looking statements and information are based upon reasonable assumptions and expectations, the reader should not place undue reliance on forward-looking statements and information because they involve known and unknown risks, uncertainties and other factors, many of which are beyond the control of the Trust, which may cause our actual results, performance or achievements to differ materially from anticipated future results, performance or achievement expressed or implied by such forward-looking statements and information.

Factors that could cause actual results to differ materially from those contemplated or implied by forward-looking statements include, but are not limited to: the successful completion of the redemption by BOX of the units not owned by BPY and its subsidiaries; risks incidental to the ownership and operation of real estate properties including local real estate conditions; the impact or unanticipated impact of general economic, political and market factors in Canada; the ability to enter into new leases or renew leases on favourable terms; business competition; dependence on tenants’ financial condition; the use of debt to finance the Trust’s business; the behavior of financial markets, including fluctuations in interest rates; equity and capital markets and the availability of equity and debt financing and refinancing within these markets; risks relating to the Trust’s insurance coverage; the possible impact of international conflicts and other developments including terrorist acts; potential environmental liabilities; changes in tax laws and other tax related risks; dependence on management personnel; illiquidity of investments; the ability to complete and effectively integrate acquisitions into existing operations and the ability to attain expected benefits therefrom; operational and reputational risks; catastrophic events, such as earthquakes and hurricanes; and other risks and factors detailed from time to time in our documents filed with the securities regulators in Canada and the United States.

Caution should be taken that the foregoing list of important factors that may affect future results is not exhaustive. When relying on the Trust’s forward-looking statements or information, investors and others should carefully consider the foregoing factors and other uncertainties and potential events. Except as required by law, the Trust undertakes no obligation to publicly update or revise any forward-looking statements or information, whether written or oral, that may be as a result of new information, future events or otherwise.

FOR FURTHER INFORMATION PLEASE CONTACT:

Contact: Sherif El-Azzazi Director, Investor Relations Tel: (416) 359-8593 Email: sherif.elazzazi@brookfield.com

INDUSTRY:

Financial Services – Commercial and Investment Banking

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Contact: Sherif El-Azzazi Director, Investor Relations Tel: (416) 359-8593 Email: sherif.elazzazi@brookfield.com}

Globenewswire

PADDLING TOWARDS RECONCILIATION WITH CANADA’S INDIGENOUS PEOPLES

April 20, 2017 by The Canadian Press

FOR: JESUITS IN ENGLISH CANADA

Toronto, April 20, 2017 (GLOBE NEWSWIRE) — More than 30 people, comprised of Indigenous, Jesuit, English and French Canadian paddlers, will embark on a month-long, 850-kilometre canoe trip July 21 in response to the Calls to Action of the Truth and Reconciliation Commission.

Following a traditional First Nations canoe trade route, the Canadian Canoe Pilgrimage (CCP) will begin at Midland, Ontario up Georgian Bay, travel across the French River, Lake Nipissing, the Mattawa and Ottawa Rivers, and end near Montreal.

“We are retracing this historic route on the 150th anniversary of Canada as a nation, but more importantly we are trying to work for reconciliation,” says Erik Sorensen, SJ, Project Manager of the CCP. “As a member of the Jesuits, a group that had a residential school that played an integral role in colonization efforts by early Europeans, there is a collective healing that I am participating in. And we are changing the way we do things.”

“I am hoping to learn a lot about the cultures that are going to be there,” says Andrew Starblanket, who is Nehiyaw and will be representing the Starblanket First Nation in Saskatchewan on the trip. “I guarantee that I’m going to learn a lot about myself and others.”

“Ontario’s 150th anniversary is an opportunity for us all to reflect on who we are and what we hope to be,” said Eleanor McMahon, Minister of Tourism, Culture and Sport. “The Canadian Canoe Pilgrimage will give people the chance to connect with a meaningful part of our history, experience our province’s breathtaking scenery firsthand, and contemplate all that we can achieve by working together.”

Jesuit Pope Francis promotes a “culture of encounter,” a culture where we engage others where they are at, offer welcome and hospitality, and are moved with compassion and the desire to treat all people with dignity. “This encounter is not about anything so specifically active, it’s much more about just being with each other, across our respective cultures and traditions,” says Kevin Kelly, SJ, a CCP co-organizer. “Encountering each other is about being ourselves and being open. This immersion experience into nature will also help participants increase their understanding of the current ecological crisis we face, especially the importance of water and our respect for and treatment of it.”

The CCP tentative itinerary below, shows major landfalls, but please be advised there may be changes due to logistical considerations and weather related contingencies.

July 21 – Departs Sainte-Marie among the Hurons (Midland, ON)

July 31 – North Bay, ON

August 2 – Mattawa, ON

August 6 – Pembroke, ON

August 9 – Ottawa, ON

August 14 – Montreal, Quebec

August 15 – Kahnawake First Nation (close to Montreal)

Members of the public will be able to join the CCP at special events at major stops along the route.

The Canadian Canoe Pilgrimage has been made possible by the generosity of donors including The Miller Group, the Ontario 150 Community Celebration Fund, the Canadian Heritage River System, Parks Canada, and Ontario Parks. Also thanks to Sainte-Marie among the Hurons and Martyrs’ Shrine for hosting the launch event on July 21.

About the Canadian Canoe Pilgrimage

The Canadian Canoe Pilgrimage (CCP) is a project inspired by Canada’s Truth and Reconciliation Commission (TRC) with the hope of encouraging intercultural and interreligious dialogue and learning. Participants, both Indigenous and non-Indigenous, will be immersed in each other’s customs and traditions. Through this immersion, the goal is to foster deep respect, trust, dialogue and hopefully friendship, the building blocks for reconciliation.

The canoe route is a traditional First Nations trading route that was travelled by early European settlers such as Samuel de Champlain and Jean de Brébeuf, who were welcomed and guided by the Indigenous Peoples of this land. This pilgrimage will begin at Sainte-Marie among the Hurons in Midland, on the shore of Georgian Bay, on July 21 and end on August 15 on the St. Lawrence River at the Kahnawake First Nation, close to Montreal. The community of paddlers making this 850-kilometre, 25-day voyage is comprised of Indigenous Peoples, Jesuits, English and French Canadians, men and women – all desiring to travel together on a path of healing and friendship. The route follows a similar one paddled by 24 young Jesuits in 1967. For more information, and to donate, please go to: www.canoepilgrimage.com.

About the Jesuits in English Canada

The Jesuits, an order of priests and brothers in the Roman Catholic Church, have worked in Canada for more than 400 years. They have responsibility for the direction of schools, churches, retreat houses, and a variety of social justice ministries that span from St. John’s, Newfoundland and Labrador to Vancouver, British Columbia. They have worked closely with the TRC and issued a public Statement of Reconciliation in 2013. The Jesuits are currently implementing the Calls to Action described by the TRC. For more details please visit www.jesuits.ca.

For news media and government information, please contact:

Mark Hunter LaVigne, MAJ, APR, FCPRSMark.lavigne@hunterlavigne.com416-884-2018 (mobile)

Erica Zlomisliccdacommunications@jesuits.org416-962-4500 X225855-962-4500 X225416-333-2585 (mobile)

For project information, and to discuss donations and grants, please contact:

Erik Sorensen, SJcanoe.pilgrimage@jesuits.net647-850-5411 (mobile)

Attachments:

A photo accompanying this announcement is available at http://www.globenewswire.com/NewsRoom/AttachmentNg/e029ab4f-88c5-44a2-9dcd-da1f92261a64

Attachments:

A photo accompanying this announcement is available at http://www.globenewswire.com/NewsRoom/AttachmentNg/4e3f534e-7939-4e2e-a886-d4a9fc1e1218

Attachments:

A photo accompanying this announcement is available at http://www.globenewswire.com/NewsRoom/AttachmentNg/460cb5e9-246c-46a8-83eb-97a9ac8be7aa

FOR FURTHER INFORMATION PLEASE CONTACT:

Erica Zlomislic Jesuits in English Canada 416.962.4500 cdacommunications@jesuits.org

INDUSTRY:

Miscellaneous – Miscellaneous

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Erica Zlomislic Jesuits in English Canada 416.962.4500 cdacommunications@jesuits.org}

Globenewswire

Denbury Announces Release Date for First Quarter 2017 Results and Conference Call

April 20, 2017 by The Canadian Press

FOR: DENBURY RESOURCES INC.

PLANO, Texas, April 20, 2017 (GLOBE NEWSWIRE) — Denbury Resources Inc. (NYSE:DNR) (“Denbury” or the “Company”) will host a conference call to review and discuss first quarter 2017 financial and operating results on Thursday, May 4, 2017 at 10:00 A.M. (Central). The Company plans to issue its financial and operating results prior to the market opening on the same day. Individuals who would like to participate should dial the applicable dial-in number listed below ten minutes before the scheduled start time.

What: Denbury Resources First Quarter 2017 Results Conference Call

Date: Thursday, May 4, 2017

Time: 10:00 A.M. (Central) / 11:00 A.M. (Eastern)

Dial-in numbers: 800.230.1093 (domestic) and 612.332.0226 (international)

Conference ID number: 361972

A live presentation webcast of the conference call will be available on the Company’s website at www.denbury.com. The webcast will be archived on the website and a telephonic replay will be accessible for at least one month after the call by dialing 800.475.6701 (domestic) or 320.365.3844 (international) and entering the conference ID number: 361972.

Denbury is an independent oil and natural gas company with operations focused in two key operating areas: the Gulf Coast and Rocky Mountain regions. The Company’s goal is to increase the value of its properties through a combination of exploitation, drilling and proven engineering extraction practices, with the most significant emphasis relating to carbon dioxide enhanced oil recovery (CO2 EOR) operations. For more information about Denbury, please visit www.denbury.com.

FOR FURTHER INFORMATION PLEASE CONTACT:

DENBURY CONTACTS: John Mayer, Investor Relations, 972.673.2383 Ben Nelson, Financial Analyst, 972.673.2787

INDUSTRY:

Energy and Utilities – Oil and Gas

SUBJECT: CAL

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: DENBURY CONTACTS: John Mayer, Investor Relations, 972.673.2383 Ben Nelson, Financial Analyst, 972.673.2787}

Globenewswire

Petrocapita Provides an Update on Proceeds of Debentures

April 20, 2017 by The Canadian Press

FOR: PETROCAPITA INCOME TRUSTCNSX SYMBOL: PCE.UNCSE SYMBOL: PCE.UNCSE SYMBOL: PCE.UN.CNDate issue: April 20, 2017Time in: 8:16 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 20, 2017) – Petrocapita Income Trust
(CNSX:PCE.UN)(CSE:PCE.UN)(CSE:PCE….

EPA chief delays methane rule at behest of oil and gas firms

April 20, 2017 by The Canadian Press

WASHINGTON — The Environmental Protection Agency is again moving to derail Obama-era regulations aimed at reducing pollution from the fossil fuel industry.

EPA Administrator Scott Pruitt announced Wednesday he’s issued a 90-day delay for oil and gas companies to follow a new rule requiring them to monitor and reduce methane leaks from their facilities. Pruitt says the agency will now reconsider the 2016 measure, which the companies were required to comply with by this June.

It is the latest in a slew of actions by Pruitt to set aside environmental regulations opposed by corporate interests. The American Petroleum Institute and other industry groups petitioned Pruitt to scrap the requirement.

Methane is a potent greenhouse gas, causing up to 100 times more global warming than the same amount of carbon dioxide.

Michael Biesecker, The Associated Press

TransAlta commits to phase out coal power years ahead of government deadline

April 20, 2017 by The Canadian Press

CALGARY — TransAlta Corp. CEO Dawn Farrell says the company has committed to phase out its coal-fired power plants years ahead of Alberta government deadlines.

Speaking at the company’s annual meeting Thursday, Farrell said the company will shut some coal units by 2018, while converting others to natural gas to be free of coal-fired power plants by the end of 2023, six years ahead of a deadline set by the provincial government.

The move comes after what the board of directors said was the most significant period in many years as the company reached an agreement with the Alberta government on compensation for phasing out coal.

The board awarded Farrell $2.73 million in incentive compensation as part of her $7.39 million total compensation for what it said was extraordinary leadership, but shareholders disagreed, voting Thursday against a non-binding resolution on the executive compensation plan with 53 per cent opposed.

The coal phase-out plan has TransAlta (TSX:TA) shutting down the 560 megawatts of generation from Sundance Unit 1 and 2 by the start of 2018, two years ahead of a federally required date, while applying to keep open the option of restarting Unit 2 between 2019 and 2021.

The company has also committed to convert three other Sundance units and two Keephills units, representing about 2,400 megawatts of capacity, from coal to gas by 2023, which it says will extend the life of the units into the mid-2030s.

Farrell said TransAlta would immediately start securing the up to 700 million cubic feet of gas per day that will be required to power the plants, including construction of a needed pipeline.

TransAlta is also working to move forward on its Brazeau hydro expansion project in Alberta, but because of a cap on the province’s utility market share, Farrell said the company is looking elsewhere for other expansion projects.

The Alberta government has committed to phasing out coal-fired power plants by 2030, and has a target of 30 per cent of power coming from renewables by then.

Besides its Alberta assets, TransAlta also has generating capacity in British Columbia, Ontario, Quebec, New Brunswick, as well as in the United States and Australia.

The Canadian Press

Suncor Energy to release first quarter 2017 financial results and hold Annual General Meeting of shareholders

April 20, 2017 by The Canadian Press

FOR: SUNCOR ENERGY INC.
TSX SYMBOL: SU
NYSE SYMBOL: SU

Date issue: April 20, 2017
Time in: 6:35 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 20, 2017) – Suncor will release its
first quarter financial results on Wednesday, April 26, 2017 before 8:00 p.m.
MT (10:00 p.m. ET).

A webcast to review the first quarter will be held at 7:30 a.m. MT (9:30 a.m.
ET) on Thursday, April 27, 2017. Representing management will be Steve
Williams, president and chief executive officer and Alister Cowan, executive
vice president and chief financial officer. A question and answer period with
analysts will follow brief remarks from management. Steve Douglas, vice
president, Investor Relations will host.

Please note, telephone lines are limited and reserved for those who intend to
ask a question.

To participate in the conference, go to suncor.com/webcasts.

An archive of the webcast will be available on suncor.com/webcast.

If you are an analyst or media and would like to participate in the Q&A period:

/T/

— if calling from North America: 1 866-219-5885
— if calling from outside North America: +1 209-905-5918

/T/

Suncor has scheduled its second quarter financial release date for Wednesday,
July 26, 2017.

Annual General Meeting

Suncor will host its Annual General Meeting at 10:30 a.m. MT (12:30 p.m. ET) on
Thursday, April 27, 2017.

/T/

The Metropolitan Conference Centre
333 4th Avenue SW
Calgary, Alberta

/T/

The event will be webcast live on suncor.com/webcasts and archived for 90 days.

Suncor Energy is Canada’s leading integrated energy company. Suncor’s
operations include oil sands development and upgrading, offshore oil and gas
production, petroleum refining, and product marketing under the Petro-Canada
brand. A member of Dow Jones Sustainability indexes, FTSE4Good and CDP, Suncor
is working to responsibly develop petroleum resources while also growing a
renewable energy portfolio. Suncor is listed on the UN Global Compact 100 stock
index and the Corporate Knights’ Global 100. Suncor’s common shares (symbol:
SU) are listed on the Toronto and New York stock exchanges.

For more information about Suncor, visit our website at suncor.com, follow us
on Twitter @SuncorEnergy or together.suncor.com

– END RELEASE – 20/04/2017

For further information:
Investor inquiries:
800-558-9071
invest@suncor.com
OR
Media inquiries:
403-296-4000
media@suncor.com

COMPANY:
FOR: SUNCOR ENERGY INC.
TSX SYMBOL: SU
NYSE SYMBOL: SU

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170420CC0130

Press Release from Marketwired 1-866-736-3779

Toronto Real Estate Board Responds to Ontario’s Fair Housing Plan

April 20, 2017 by The Canadian Press

FOR: TORONTO REAL ESTATE BOARD

TORONTO, April 20, 2017 (GLOBE NEWSWIRE) — Toronto Real Estate Board CEO John DiMichele has released a statement in response to the new measures announced today by the Ontario Government for homebuyers and renters.

“The Toronto Real Estate Board is encouraged that all levels of government are making the state of the housing market a priority; however, TREB strongly believes that public policy decisions with regard to the housing market should be evidence-based and supported by empirical data. In this regard, it is not clear that the issues targeted by the policies announced today are fully understood at this point, nor is it clear how effective these policies will be, or if they will have unintended outcomes.

TREB continues to believe that more empirical evidence is needed to fully understand the issues that governments are attempting to address. TREB has participated in discussions with policy makers and has taken the initiative to conduct research that has contributed valuable data, and we will continue to do so.

With regard to REALTOR practices as it relates to the home bidding process or representation of sellers and buyers, TREB welcomes a review of the Real Estate and Business Brokers Act, which REALTORS are currently obligated to comply with and is administered by the Real Estate Council of Ontario (RECO). The rules are specific in terms of what REALTORS are required to do and TREB Members follow the rules as set out by REBBA and RECO.” – John DiMichele, TREB CEO

Government Announcement: https://news.ontario.ca/opo/en/2017/04/making-housing-more-affordable.html

Greater Toronto REALTORS® are passionate about their work. They are governed by a strict Code of Ethics and share a state-of-the-art Multiple Listing Service®. Over 48, 000 residential and commercial TREB Members serve consumers in the Greater Toronto Area. TREB is Canada’s largest real estate board.

FOR FURTHER INFORMATION PLEASE CONTACT:

Media Inquiries: Mary Gallagher, Senior Manager Public Affairs (416) 443-8158 maryg@trebnet.com

INDUSTRY:

Miscellaneous – Miscellaneous

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Media Inquiries: Mary Gallagher, Senior Manager Public Affairs (416) 443-8158 maryg@trebnet.com}

Globenewswire

In his own words: Text of Trump’s latest complaints about Canadian trade

April 20, 2017 by The Canadian Press

WASHINGTON — U.S. President Donald Trump took several shots at Canada again Thursday, complaining about its trade practices in several areas. He made the remarks during a ceremony in the Oval Office where he signed an executive order related to steel.

In his own words:

“I want to just add — I wasn’t going to do this, but I was in Wisconsin the other day, and I want to end by saying that Canada, what they’ve done to our dairy farm workers is a disgrace. It’s a disgrace.

“I spent time with some of the farmers in Wisconsin, and, as you know, rules, regulations, different things have changed. And our farmers in Wisconsin and New York State are being put out of business, our dairy farmers. And that also includes what’s happening along our northern border states with Canada, having to do with lumber and timber.

“The fact is, NAFTA — whether it’s Mexico or Canada — is a disaster for our country. It’s a disaster. It’s a trading disaster. And we’ll be reporting back sometime over the next two weeks as to NAFTA and what we’re going to do about it. But what happened to our dairy farmers in Wisconsin and New York State — we’re not going to let it happen.

“We can’t let Canada or anybody else take advantage and do what they did to our workers and to our farmers. And again, I want to also just mention, included in there is lumber — timber — and energy. So we’re going to have to get to the negotiating table with Canada very, very quickly.

“Again, just to tell you, this is another NAFTA disaster, and we’re not going to let it continue onward.”

The Canadian Press

OneRoof Energy Group, Inc. Announces Voting Results of Special Shareholders’ Meeting

April 20, 2017 by The Canadian Press

FOR: ONEROOF ENERGY GROUP, INC.TSX VENTURE SYMBOL: ONDate issue: April 20, 2017Time in: 5:37 PM eAttention:
SAN DIEGO, CALIFORNIA–(Marketwired – April 20, 2017) – OneRoof Energy Group,
Inc. (“OneRoof Energy” or the “Company”) (TSX VENTURE:ON) is pleas…

Kelt Announces Results of Shareholders’ Meeting

April 20, 2017 by The Canadian Press

FOR: KELT EXPLORATION LTD.TSX Symbol: KELDate issue: April 20, 2017Time in: 4:51 PM eAttention:
CALGARY, AB –(Marketwired – April 20, 2017) – Kelt Exploration Ltd. (TSX:
KEL) (“Kelt” or the “Company”) is pleased to announce that all matters
presented…

AIAG Marks Another Milestone With 2,000th New Member

April 20, 2017 by The Canadian Press

FOR: AUTOMOTIVE INDUSTRY ACTION GROUP (AIAG)

SOUTHFIELD, Mich., April 20, 2017 (GLOBE NEWSWIRE) — Last August, the Automotive Industry Action Group hit a milestone in membership, welcoming its 1,500th new member into the AIAG community. Today, just seven months later, the association celebrates another accomplishment: surpassing the 2,000 member mark.

“Achieving 2,000 members is a great sign that the value of the standards and best practices created by the industry for the industry at AIAG are gaining even more recognition of the value they provide the entire automotive supply chain,” says David A. Lalain, AIAG’s vice president, member services. “Of course, the true benefit is only realized when these standards and best practices are utilized by the entire industry, from the OEMs and Tier Ones to the Tier Twos and beyond. More and more companies are realizing that membership makes it easier for them to access the tools they need to work at their best and keep current on the latest industry developments.”

Nancy Malo, an AIAG membership manager, notes that current members have played a significant role in continuing the upswing in the AIAG member community. “Reaching 2,000 member companies was achieved with help from our existing, dedicated members who consistently communicate AIAG’s value to their sub-tier supply base, and we thank them for that,” she says. “In fact, our larger members believe so strongly in the work the industry does at AIAG that they’re sponsoring 5-year memberships for smaller suppliers who qualify. They want the entire industry to improve as a whole through the best practices developed at AIAG.”

Kathryn LaFerle, also an AIAG membership manager, notes that AIAG’s work to revitalize the sub-tier supply base has contributed to this latest membership milestone. “We are particularly focused on attracting and servicing the needs of emerging automotive professionals,” she says. “For example, those new to the industry enjoy monthly Future Automotive Experts meetings, which feature a talk by an automotive expert followed by Q&A and networking. Topics include quality, leadership, and how to grow a career in automotive.”

“The popularity of these meetings has grown dramatically because they give new automotive professionals access to successful industry experts,” says LaFerle. “And the experts get a lot out of it as well because they engage with the industry’s rising talent.”

The AIAG membership team points to the recent rise in automotive professionals, supported by the revitalization of college-level and adult continuing education programs with real-world automotive industry content. AIAG is also working hard to attract minority-owned businesses and collaborate with sister organizations in the Southeast U.S., Canada, and Mexico to support increasing demand for local sources of advanced manufacturing skills.

J. Scot Sharland, AIAG’s executive director, adds that as AIAG drives awareness, access, and utilization of industry standards and allied best practices across the industry, the natural result is a growing number of automotive companies interested in joining the movement. “Together, we are mitigating risk and managing uncertainty for all of the automotive supply chain,” says Sharland. “Our rapidly growing membership is thriving due to self-assessments, best practices, standards, and training, which is resulting in more predictable manufacturing outcomes.”

About AIAGThe Automotive Industry Action Group is a unique not-for-profit organization where OEMs, suppliers, service providers, government entities, and individuals in academia have worked collaboratively for more than 30 years to drive down costs and complexity from the supply chain. AIAG membership includes preeminent manufacturers and many of their parts suppliers and service providers. To learn more about AIAG membership, call 248.358.9780 or visit www.joinAIAG.org.

FOR FURTHER INFORMATION PLEASE CONTACT:

Contact: Greg Creason, AIAG Ph. 248.358.9775

INDUSTRY:

Miscellaneous – Miscellaneous

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Contact: Greg Creason, AIAG Ph. 248.358.9775}

Globenewswire

Savanna to Release Q1 2017 Results on May 12, 2017

April 20, 2017 by The Canadian Press

FOR: SAVANNA ENERGY SERVICES CORP.TSX SYMBOL: SVYDate issue: April 20, 2017Time in: 3:33 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 20, 2017) – Savanna Energy Services
Corp. (“Savanna” or the “Company”) (TSX:SVY) intends to release its First…

Saudi oil minister says production cuts may need to continue

April 20, 2017 by The Canadian Press

ABU DHABI, United Arab Emirates — Saudi Arabia’s oil minister on Thursday suggested that production cuts agreed to by OPEC members and countries outside of the cartel may need to continue to help shore up crude oil prices.

The comments by Khalid al-Falih carry significant weight as the kingdom is one of the world’s top oil producers. They come as the price per barrel stand above $50 and increases in U.S. shale oil production threaten to keep them low.

“There is an initial agreement but it has not been communicated to all the countries yet that we might be forced to extend in order to reach our goal,” al-Falih said in a speech at an oil conference in Abu Dhabi, the capital of the United Arab Emirates.

OPEC agreed in late November to cut its production by 1.2 million barrels a day for six months, its first cut since 2008. Nearly a dozen other countries including Russia pledged in December to cut an additional 558,000 barrels a day.

Crude oil sold for over $100 a barrel in the summer of 2014, before bottoming out below $30 a barrel in January 2016.

Significant wild cards remain, however. President Donald Trump has pledged to free up more oil drilling in the United States. The global economy remains weak as well. Meanwhile, shale oil production has started growing again in the U.S. while Iran rushes to produce as much as it can to make up for years of economic sanctions it suffered over its contested nuclear program.

Talking about shale, Emirati Energy Minister Suhail al-Mazroui said producers involved in the cut made the decision “because we care about the balance in the market.”

“This sacrifice cannot be taken as a sacrifice where someone else can benefit 100 per cent,” he said.

Fay Abuelgasim, The Associated Press

Benu Networks to Participate in Upcoming Industry Events

April 20, 2017 by The Canadian Press

FOR: BENU NETWORKS

BILLERICA, Mass., April 20, 2017 (GLOBE NEWSWIRE) — Benu Networks, a leading provider of innovative virtual network solutions that enable service providers to rapidly create and deliver next generation IP services, today announced participation in two upcoming industry events, NFV World Congress and ANGA COM.

At both events, Benu Networks will highlight how service providers around the world have utilized its Virtual Service Edge platform to overcome network challenges, enable the rapid deployment of new, compelling IP-based services, and generate profitable revenue streams. Details of Benu Networks’ presence at each event is as follows:

• NFV World Congress: May 2 – 5, 2017, Doubletree Hilton Hotel, San Jose, CA

Ajay Manuja, Benu Networks’ V.P. of Engineering, will be participating in the panel debate entitled “Commercializing NFV” to be held on Wednesday, May 3, 2017, from 5:30pm to 6:05pm.
Visit Benu Networks at Booth #22 in the exhibition area (Bayshore Ballroom).

• ANGA COM: May 30 – June 1, 2017, Koelnmesse/Cologne Fair Grounds, Köln, Germany

Alkesh Patel, Benu Networks’ General Manager of EMEAI, will be participating in the panel entitled “Challenges & Opportunities of Taking the Service Experience to the Cloud” to be held in Room #2 on Tuesday, May 30, 2017 from 4:30pm to 5:45pm.

To request a meeting with Benu Networks at these events, please email events@benunets.com.

Benu Networks’ Virtual Service Edge (VSE) platform seamlessly integrates with service providers’ operations and business systems to facilitate a comprehensive network solution that is fully virtualized to enable security, scalability and service agility. The VSE solution enables rapid cloud-based service deployment, dynamic service control, and increased customer care responsiveness. The VSE dramatically improves service providers’ time-to-market with differentiated managed service offerings for Mobile Wi-Fi, Managed Business Networking and Managed Home Networking services.

“Benu Networks is pleased to participate in these important industry events,” stated Mads Lillelund, CEO, Benu Networks. “These forums are a perfect setting to showcase how Benu Networks’ VSE platform is a catalyst for cost-effectively launching new customized services, attracting and retaining subscribers, increasing service revenues, and enabling a competitive advantage for service providers in today’s fiercely competitive marketplace.”

About Benu NetworksBenu Networks’ carrier-class Virtual Service Edge (VSE) software platform enables the rapid creation and delivery of next generation IP services over a converged infrastructure, and empowers service providers to increase revenue, expand market leadership, and meet the dynamic needs of their business, residential and mobile customers. For more information, please visit the Benu Networks’ website: www.benunetworks.com. Follow us on Twitter @benunets.

FOR FURTHER INFORMATION PLEASE CONTACT:

For Benu Networks, please contact: Kelly Friedland Director of Marketing 781-640-4864 kfriedland@benunets.com

INDUSTRY:

Computers and Software – Software

SUBJECT: CAL

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: For Benu Networks, please contact: Kelly Friedland Director of Marketing 781-640-4864 kfriedland@benunets.com}

Globenewswire

Introducing Angoss Version 10.3 Software Suite Release and KnowledgeENTERPRISE unveil

April 20, 2017 by The Canadian Press

FOR: ANGOSS SOFTWARE CORPORATION

TORONTO, April 20, 2017 (GLOBE NEWSWIRE) — Angoss Software Corporation (Angoss) announces the release of version 10.3 Software Platform and the launch of KnowledgeENTERPRISE product for Big Data access, analytics, and visualization.

In version 10.3 Angoss has made significant user interface (UI) enhancements to its product suite: KnowledgeSEEKER™; KnowledgeSTUDIO™; KnowledgeENTERPRISE; KnowledgeREADER™; KnowledgeCORE™; and InsightOPTIMIZER™. This new look and feel now provides users with a modern, intuitive, and easy-to-use software interface that further minimizes the learning curve, increases collaboration, and improves operational efficiencies.

Most importantly, with the rising demand for Big Data enabled data science platforms and noticeable enterprise IT trends, Angoss has launched its Big Data ready product, KnowledgeENTERPRISE. Armed with Apache Spark technology and Angoss’ advanced data mining software capabilities, KnowledgeENTERPRISE gears its users with unprecedented access to analyze data within Big Data repositories like Hadoop HDFS, Amazon S3, Cassandra, etc. This all-encompassing software solution enables access to open source machine-learning libraries, Big Data technologies, collaboration and governance capabilities, comprehensive advanced analytics functionality, and numerous deployment options allowing users to overcome challenges in Big Data ingestion, access, and results interpretation.

With the launch of KnowledgeENTERPRISE, Angoss enables businesses to streamline their various analytics tools by providing companies with access to a single, fully-integrated and scalable Big Data application that not only considerably reduces infrastructure costs, resources, and maintenance but also enables its users to run all advanced analytics tasks in their Big Data frameworks.

Additionally, KnowledgeENTERPRISE boasts numerous collaboration functionalities such as an interactive UI, analytical flexibility which enables custom coding in Python, R, language of SAS, SQL and PMML, BI tool integration with Tableau and Qlik, automation, and governance features that help organizations institutionalize knowledge and promote collaboration across heterogeneous teams of different skills and tool requirements. These, along with comprehensive data mining capabilities, Big Data access enablement, and various deployment options make this enterprise platform a perfect choice for unifying infrastructure, technology, and data science teams within organizations.

“Enabling Big Data access and data insight discovery for our customers was the main driving force behind the design of KnowledgeENTERPRISE. Doing it with ease was the next,” said Vikram Gaitonde, Vice President of Product Management at Angoss. “We want our users to experience what it is to work with a single, user-friendly application that performs all advanced analytics and data processing in the customers’ big data environment. With our recent positioning as a ‘Leader’ in the Forrester Predictive Analytics and Machine Learning Wave we are well on our way to becoming your primary advanced analytics platform.”

About Angoss Software Corporation

Angoss is a global leader in delivering advanced analytics to businesses looking to improve performance across risk, marketing and sales. With a suite of big data analytics software solutions and consulting services, Angoss delivers powerful approaches that provide you with a competitive advantage by turning your information into actionable business decisions.

Many of the world’s leading organizations in financial services, insurance, retail and high tech rely on Angoss to grow revenue, increase sales productivity and improve marketing effectiveness while reducing risk and cost. Headquartered in Toronto, Canada, with offices in the United States, United Kingdom and Singapore, Angoss serves customers in over 30 countries worldwide. For more information, visit the www.angoss.com.

Follow Angoss on Twitter for continuous company updates: @Angoss

FOR FURTHER INFORMATION PLEASE CONTACT:

Media Contact: Joanna Balkowski Senior Product Marketing Manager 416-593-2439 jbalkowski@angoss.com

INDUSTRY:

Computers and Software – Software

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Media Contact: Joanna Balkowski Senior Product Marketing Manager 416-593-2439 jbalkowski@angoss.com}

Globenewswire

Altair Wins 2016 Boeing Performance Excellence Award

April 20, 2017 by The Canadian Press

FOR: ALTAIR ENGINEERING INC.

TROY, Mich., April 20, 2017 (GLOBE NEWSWIRE) — Altair’s product development services division Altair ProductDesign is honored to receive a 2016 Boeing Performance Excellence Award. The Boeing Company issues the award annually to recognize suppliers who have achieved superior performance. To qualify for the award, Altair maintained a silver composite performance rating for each month of the 12-month performance period, from Oct. 1, 2015, to Sept. 30, 2016. Altair has received this award for outstanding achievement for the fourth year in a row and for the fifth time in the last seven years.

A photo accompanying this announcement is available at http://www.globenewswire.com/NewsRoom/AttachmentNg/b4239ac7-61aa-42e8-bc89-71fa2aaa9eba.

“Altair ProductDesign is honored to receive this award for a fifth time”, said Mak Gilbert, Program Manager at Altair ProductDesign. “We truly value Boeing’s appreciation and recognition of the consistently smart, hard work our engineers conduct daily to support their design of lightweight, high performing aircraft,” he said.

The Altair ProductDesign approach to aerospace design includes an aggressive application of simulation technologies upfront in the development process. This ‘Simulation Driven Innovation’ philosophy allows us to find the optimal balance between weight, performance and cost for products being developed and results in a program with reduced risk and shorter cycle times to deliver an aircraft, helicopter or spacecraft that meets functional attributes and mass targets on time.

“We are delighted to have been chosen once again by Boeing. We strive to help Boeing produce great products that are engineered for performance, efficiency, and safety. This award is an outstanding recognition of the exceptional Altair engineers that support Boeing engineering goals and objectives,” said Brett Chouinard, Chief Operating Officer, Altair.

For more information on the full range of Altair ProductDesign design solutions and services please visit www.altairproductdesign.com.

About ALTAIR

Altair is focused on the development and broad application of simulation technology to synthesize and optimize designs, processes and decisions for improved business performance. Privately held with more than 2,600 employees, Altair is headquartered in Troy, Michigan, USA and operates more than 50 offices throughout 22 countries. Today, Altair serves more than 5,000 corporate clients across broad industry segments. To learn more, please visit www.altair.com.

FOR FURTHER INFORMATION PLEASE CONTACT:

Media Contacts Altair: Corporate / Americas / Asia Pacific Biba A. Bedi +1.757.224.0548 x 406 biba@altair.com Europe / The Middle East / Africa Evelyn Gebhardt +49 6421 9684351 gebhardt@bluegecko-marketing.de

INDUSTRY:

Computers and Software – Software

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Media Contacts Altair: Corporate / Americas / Asia Pacific Biba A. Bedi +1.757.224.0548 x 406 biba@altair.com Europe / The Middle East / Africa Evelyn Gebhardt +49 6421 9684351 gebhardt@bluegecko-marketing.de}

Globenewswire

Sprott Resource Holdings Announces Closing of Fully Subscribed Marketed Offering

April 20, 2017 by The Canadian Press

FOR: SPROTT RESOURCE HOLDINGS

TORONTO, April 20, 2017 (GLOBE NEWSWIRE) — Sprott Resource Holdings Inc. (“SRHI”) (TSX:SRHI) is pleased to announce that it has closed its previously announced “best efforts” marketed offering (the “Offering”) of units (the “Offered Units”) made pursuant to an agency agreement dated April 3, 2017 between SRHI and a syndicate of agents led by Sprott Capital Partners, a division of Sprott Private Wealth LP, and including Haywood Securities Inc.

Pursuant to the Offering, SRHI sold 120,000,000 Offered Units at a price of $0.25 per Offered Unit for gross proceeds of $30,000,000. Each Offered Unit consisted of one class “A” common share in the capital of SRHI (a “Common Share”) and one Common Share purchase warrant (a “Warrant”). The Warrants expire on February 9, 2022 and have an exercise price of $0.333 per Common Share.

As previously announced, SRHI intends to use the net proceeds of the Offering towards making investments in the natural resource sector and for general working capital purposes.

The Offering was completed pursuant to a short form prospectus filed in each of the provinces of Canada other than Quebec. A copy of the short form prospectus, which contains important information relating to the Units, is available on SEDAR at www.sedar.com.

The Offered Units, Common Shares and Warrants, as well as the Common Shares issuable upon exercise of the Warrants, have not been and will not be registered under the United States Securities Act of 1933, as amended (the “U.S. Securities Act”), or any securities or “blue sky” laws of any of the states of the United States. Accordingly, such securities may not be offered or sold within the United States except in accordance with an exemption from the registration requirements of the U.S. Securities Act and applicable state securities laws.

About Sprott Resource Holdings Inc.

SRHI is a publicly-listed corporation transitioning into a diversified holding company focused on holding businesses in the natural resource industry. Based in Toronto, SRHI is part of the Sprott Group of Companies and is managed by a team of leading resource investment professionals. SRHI’s current holdings are concentrated in the mining, energy and agriculture sectors. SRHI takes an active role in the companies in which it invests and is committed to being a high-value partner to the management teams it backs and the co-investors who invest alongside SRHI. For more information about SRHI, please visit www.sprottresource.com.

Forward-Looking Information and Statements

Certain statements in this press release contain forward-looking information (collectively referred to herein as the “Forward-Looking Statements”) within the meaning of applicable securities laws including, but not limited to, statements about the expected use of proceeds from the Offering and expectations regarding trading on the TSX.

Forward-Looking Statements are based on a number of expectations or assumptions which have been used to develop such statements and information but which may prove to be incorrect. Although management believes the expectations and assumptions reflected in such Forward-Looking Statements are reasonable, undue reliance should not be placed on Forward-Looking Statements because management can give no assurance that such expectations and assumptions will prove to be correct. The Forward-Looking Statements included in this press release, including with respect to the intended use of the net proceeds of the Offering, are not guarantees of future performance and should not be unduly relied upon. Such information and statements, including the assumptions made in respect thereof, involve known and unknown risks, uncertainties and other factors, which may cause actual results or events to differ materially from those anticipated in such Forward-Looking Statements. Additional information on other factors that could affect the operations or financial results of SRHI are included in reports on file with applicable securities regulatory authorities, including, but not limited to, those listed under the heading “Risks relating to the Company generally” in SRHI’s Management’s Discussion and Analysis for the Year Ended December 31, 2016. Should one or more of these risks or uncertainties materialize, or should assumptions underlying the Forward-Looking Statements prove incorrect, actual results, performance or achievements could vary materially from those expressed or implied by the Forward Looking Statements contained in this press release.

The Forward-Looking Statements contained in this press release speak only as of the date of this press release, and SRHI does not assume any obligation to publicly update or revise any of the included Forward-Looking Statements, whether as a result of new information, future events or otherwise, except as may be expressly required by applicable securities laws.

Contact:

Glen WilliamsDirector of CommunicationsSprott Group of CompaniesE: gwilliams@sprott.comT: 416-943-4394

FOR FURTHER INFORMATION PLEASE CONTACT:

INDUSTRY:

Financial Services – Commercial and Investment Banking

SUBJECT: STK

NEWS RELEASE TRANSMITTED BY Globe Newswire

^Information:

Globenewswire

PreveCeutical Signs Research and Development Agreement with UniQuest Pty Limited for Development of Caribbean Blue Scorpion Veno

April 20, 2017 by The Canadian Press

FOR: PREVECEUTICAL MEDICAL INC

VANCOUVER, British Columbia, April 20, 2017 (GLOBE NEWSWIRE) — PreveCeutical Medical Inc. (“PMI”) a health and wellness company focused on utilizing nature and science for the benefit of health-conscious consumers, is pleased to announce that it signed a research and option agreement (the “Agreement“) with UniQuest Pty Limited (“UniQuest”) for conducting a research program (the “Research Program“) for the development of Scorpion Venom-Derived Natural & Synthetic Peptides. UniQuest is the main commercialisation company for the University of Queensland (“UQ”).

PMI has an interest in the preventative health sector and is developing products derived from Caribbean Blue Scorpion Venom for the nutraceutical and eventual pharmaceutical market. This includes the CellB9 Immune System Booster product, which contains peptides that are obtained from the Caribbean Blue Scorpion. In collaboration with UniQuest, PMI would like to identify the active components (peptides) that are providing the immune boosting and tumor selective painting properties, access synthetic versions of the active peptides as an alternative to relying on milking the Caribbean Blue Scorpions, and ultimately identify other therapeutic applications for the Blue Scorpion Venom and/or active peptides.

The duration of the proposed Research Program is up to twenty-four (24) months and will encompass the identification of milked Caribbean Blue Scorpion Venom-containing peptides, chemical synthesis of natural and synthetic peptide variants stabilised with UQ’s proprietary chemistry, followed by screening the peptides in various disease models of interest to PMI and UniQuest. The proposed Research Program will be carried out in three (3) phases.

Under the Agreement, intellectual property arising from the carrying out of, results developed during, or created by the Research Program (excluding any improvements to existing intellectual property used in the Research Program) will be owned by PMI. At any time during the Research Program or for an agreed period after the completion of the Research Program, the Agreement provides PMI with an option to negotiate with UniQuest for a license (the “Licence”) to use UniQuest’s intellectual property for the commercialisation of blue scorpion venom derived products by PMI. The granting of the license is subject to the parties negotiating the terms of the License and entering into a definitive licensing agreement.

“Working with UniQuest and the University of Queensland on this research program presents PMI with unique opportunities towards developing products that promote good health and wellness. Wellness products developed from Scorpion Venom-Derived Natural & Synthetic Peptides have the potential to be utilised in a number of therapeutic applications including boosting immune systems”, said Stephen Van Deventer, PMI’s Chairman and Chief Executive Officer.

Information on these projects will be presented by Dr. Makarand Jawadekar, PMI’s Chief Science Officer, and Dr. Harendra (Harry) Parekh, of the University of Queensland’s School of Pharmacy, at PMI’s presentation on April 27, 2017.

Presentation Information:

Venue: The Fairmont Waterfront Hotel (900 Canada Pl, Vancouver, BC V6C 3L5), Malaspina Room

Date: Thursday, April 27, 2017

Time: 1:30 p.m. PDT to 6:00 p.m. PDT

Confirm your attendance, register by clicking here: https://preveceutical-presentation-2017.eventbrite.ca/

Update on Previously Announced Amalgamation and Financing

The non-brokered private placement of up to 10 million units for minimum gross proceeds of at least $1 million and maximum gross proceeds of up to $5 million (the “Financing”) being conducted by Carrara Exploration Corp. (CSE:CAA) (“Carrara”), pursuant to a previously announced amalgamation agreement, is ongoing. The amalgamation agreement provides for the acquisition of PMI by Carrara by way of a three-cornered amalgamation and a reverse take-over of Carrara by PMI. A copy of the news release announcing the Financing and a copy of the amalgamation agreement were posted on Carrara’s profile on the System for Electronic Document Analysis and Retrieval (SEDAR)’s website on March 23, 2017, and can be accessed at www.sedar.com.

About UniQuest Pty Ltd.

UniQuest is the main commercialization company of UQ, specialising in the commercialisation of intellectual property, research outcomes and expertise. UniQuest delivers commercialization outcomes which provide impact for business, the environment, global communities and society as a whole. UniQuest benchmarks in the top 10 percent globally for university-based technology transfer. UQ innovations licenced by UniQuest are now generating annual sales of over $3 billion. For example, UQ superconductor technology, through licensing arrangements, is used in two-thirds of the world’s MRIs and more than 80 million doses of the life-saving Gardasil® cervical cancer vaccine, patented by UniQuest in 1991, have been distributed throughout 121 countries, including 72 developing countries.

On Behalf of the Board of Directors,

Stephen Van DeventerChairman & CEO

Forward-Looking Statements:

This news release includes certain statements that constitute “forward-looking information” within the meaning of applicable Canadian securities laws. Readers are cautioned that forward-looking statements are not guarantees of future performance or events and, accordingly, are cautioned not to put undue reliance on forward-looking statements due to the inherent uncertainty of such statements. Statements in this news release that are not purely historical are forward-looking statements and include any statements regarding beliefs, plans, expectations and orientations regarding the future. Often, but not always, forward-looking statements can be identified by words such as “pro forma”, “plans”, “expects”, “may”, “should”, “budget”, “schedules”, estimates”, “forecasts”, “intends”, “anticipates”, “believes”, “potential” or variations of such words including negative variations thereof and phrases that refer to certain actions, events or results that may, could, would, might or will occur or be taken or achieved. Such forward-looking statements include, among others, statements as to the terms and conditions or other matters related to the Agreement, the proposed research and development services to be provided by UniQuest, the details of the Research Program, the anticipated business plans of PMI regarding the foregoing, the timing of future activities and the prospects of their success for PMI, PMI’s ability and success in executing its proposed business plans, including the Research Program and the amalgamation. Actual results could differ from those projected in any forward-looking statements due to numerous factors including risks and uncertainties relating to the inability of Carrara to complete the Financing and the inability of PMI or UniQuest, to complete the Research Program as planned and obtain any required governmental approvals, permits or financing required to carry out planned future activities. Other factors such as general economic, market or business conditions or changes in laws, regulations and policies affecting the biotechnology or pharmaceutical industry, may also adversely affect the future results or performance of PMI. There is no guarantee that any of the proposed research programs will be successful or their results can be commercialised by PMI. There is no guarantee that the Research Project or the amalgamation will be completed. These forward-looking statements are made as of the date of this news release and, unless required by applicable law, PMI assumes no obligation to update the forward-looking statements or to update the reasons why actual results could differ from those projected in these forward-looking statements. Although PMI believes that the statements, beliefs, plans, expectations, and intentions contained in this news release are reasonable, there can be no assurance that those statements, beliefs, plans, expectations, or intentions will prove to be accurate. Readers should consider all of the information set forth herein and should also refer to other periodic reports provided by PMI from time-to-time.

FOR FURTHER INFORMATION PLEASE CONTACT:

PreveCeutical Medical Inc. Suite 605 – 815 Hornby Street, Vancouver, B.C., V6Z 2E6, Canada www.preveceutical.com 1 (866) 398-1288

INDUSTRY:

Pharmaceuticals and Biotech – Biotech

SUBJECT: HLTCAL

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: PreveCeutical Medical Inc. Suite 605 – 815 Hornby Street, Vancouver, B.C., V6Z 2E6, Canada www.preveceutical.com 1 (866) 398-1288}

Globenewswire

Mitel User Group Hosts Elite Experience Event May 30-June 2

April 20, 2017 by The Canadian Press

FOR: MITEL NETWORKS

Headlined by Olympic gold medalist Michael Johnson, President and Founder of Michael Johnson Performance, and Dr. Vijay Gurbaxani, Founding Director of the Center for Digital Transformation at University of California, Irvine.
Features an Innovation Center, group training and highly-collaborative workshops with hands-on experience.
Register now for the San Antonio, Texas, event and receive a discounted rate through April 28.

TROY, Mich., April 20, 2017 (GLOBE NEWSWIRE) — The Mitel User Group, a global community driven and managed by customers of Mitel® (Nasdaq:MITL) (TSX:MNW), a global leader in enterprise communications, will hold its annual conference and general meeting May 30-June 2 welcoming members from across the Americas Region to the JW Marriott in San Antonio, Texas.

The Elite Experience event includes a full lineup of speakers with keynotes from Michael Johnson and Dr. Vijay Gurbaxani. Johnson, 13-time World and Olympic gold medalist, operates a Dallas-based Athletic Performance training center. Hear how his organization radically improved the way its coaches communicate with athletes around the world. Then, get unique insight from Dr. Gurbaxani, Founding Director of the Center for Digital Transformation at the University of California, Irvine, on the imperative of digital transformation, what companies need to focus on and how today’s technology will shape tomorrow’s business.

Mitel CEO Rich McBee and others from the company’s senior leadership team are also scheduled to speak. Come interact with leading customers and experts across government, healthcare, hospitality, education and more. Breakout sessions and product demonstrations will cover a range of solutions around cloud, collaboration, contact center, enterprise mobility and beyond.

To attend, register now and receive the discounted rate through April 28.

Quotes

“Elite Experience is a ‘must-attend’ event for getting real-world, practical solutions to your organization’s business communications challenges,” Torre Bookout, President of Americas Region, Mitel User Group. “It provides a unique opportunity to make new connections, learn best practices from peers at companies in industries like your own and start to envision how your business will evolve to enter the era of digital transformation.”

“As digital transformation accelerates worldwide, it’s redefining how companies communicate and collaborate,” said Rich McBee, CEO, Mitel. “Mitel is providing businesses a path forward, no matter their starting point or speed of journey, with communications and collaboration solutions that will allow them to leverage next-generation mobile, cloud-based productivity and IoT applications to gain a competitive advantage.”

Social Media Twitter: .@mitelusergroup hosts Elite Experience Event May 30-June 2 in San Antonio, Texas, at the JW Marriott

Tags/Keywords Mitel, Mitel User Group, Digital Transformation

About Mitel User GroupThe Mitel User Group is an independent resource for Mitel product knowledge and education on Mitel platforms, applications, services and third-party solutions. It’s a venue to share and exchange information, and communicate ideas and experiences with users from around the world. Join the Mitel User Group.

FOR FURTHER INFORMATION PLEASE CONTACT:

Contact Information Torre Bookout 479-770-1999 boardofdirectors@mitelusergroup.com

INDUSTRY:

Telecom – Telecommunication Equipment

SUBJECT: MISTS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Contact Information Torre Bookout 479-770-1999 boardofdirectors@mitelusergroup.com}

Globenewswire

Vimond Joins You.i TV Partner Program To Address Growing Demand for Packaged Video Solutions

April 20, 2017 by The Canadian Press

FOR: YOUI.TV

OTTAWA and BERGEN, Norway, April 20, 2017 (GLOBE NEWSWIRE) — You.i TV, a global leader in video experience platforms, and Vimond, experts in the development of OTT video solutions, today announced Vimond’s entry into the You.i TV Partner Program as part of a joint commitment to accelerate global availability of superior, cross-platform video experiences.

You.i TV and Vimond are providing SVOD and TV Everywhere solutions with differentiated one-stop access to the front- and back-end elements needed to achieve direct-to-consumer success. The collaboration allows customers to leverage the combined power of the Vimond Platform, a multi-tenant architecture that includes tools and controls needed to manage and deliver multi-format OTT services, and the You.i Engine experience platform, which expedites availability of best-in-class video apps at scale.

Learn more about the joint You.i TV and Vimond solution by visiting the Vimond booth SU10105C at NAB 2017 in Las Vegas.

The Vimond Platform covers the full scope of OTT back-end operations — from ingest and encoding to conditional access and business intelligence reporting — providing a comprehensive environment that addresses creative, logistical, and business needs. Vimond provides the platform for many award-winning TV Everywhere services, including Thomson Reuters, Swedish TV4 Play, TV 2, RiksTV and NRK in Norway, MTV in Finland, and C-More in Northern Europe. Vimond has also delivered revolutionary SVOD services for iflix in SE Asia and for Comcast in the USA. All of these companies are market leaders and rely on Vimond’s leading edge products for their online TV services.

“Vimond’s customer base has been built on the strength of our tool set that offers comprehensive answers to our customers’ growing DTC businesses,” said Stein Erik Sorhaug, Vice President, Product Strategy for Vimond. “Our partnership with You.i TV creates significant new value for our customers by giving them the opportunity to create video app experiences that differentiate their offerings and engage viewers across the vast universe of smartphones, tablets, smart TVs, set-top boxes and gaming consoles.”

“You.i TV and our partners are reshaping the TV landscape by delivering ‘user first’ experiences that are more engaging and better for our customers’ businesses,” said Susan Odle, Director of Business Partners for You.i TV. “By adding Vimond to our Partner Program, we’re increasing our ability to offer the advantages of the You.i Engine development environment within solutions that are designed to meet each video service provider’s needs.”

Vimond’s powerful platform is used by broadcasters and content owners around the world to efficiently manage their online video services, including live, linear and on-demand video. Vimond understands broadcasting workflows, supporting customers as they build online video services, and using the flexible and scalable platform modules to customise the solution to fit the differing requirements of each customer.

You.i Engine allows content providers to reduce cost and time-to-market by using a single codebase and the power of device graphics processing resources for the creation of video app experiences. The unique approach enables flexible app experiences that quickly can be adapted to changing content, in-app advertising and consumer needs, and that can provide UXs that are consistent across every device.

About VimondVimond Media Solutions develops modular, interoperable and custom OTT solutions for the new world of TV. Established in 2011, with headquarters in Bergen, Norway, and offices around the world – New York, Sydney, Dubai – Vimond powers services from world-leading online TV brands, such as Comcast, Fox Sports, iflix, Optus, Thomson Reuters, TV 2, TV.AE and top broadcasters and service providers globally. Vimond helps these companies adapt and grow a rapidly changing digital audience by providing unique technology and expertise. For more information on Vimond Media Solutions and its products, visit www.vimond.com .

About You.i TVYou.i TV is a privately held company whose multi-screen video app platform enables TV and media companies worldwide to create fans, engage users and convert customers. The company’s You.i Engine allows brand owners to build personalized, profitable experiences quickly on all platforms – mobile devices, set-top boxes, consoles, and streaming devices – from a single code base. Organizations such as Turner, Fox, Sony, Rogers Communications, Corus Entertainment and the Canadian Football League are spearheading direct-to-consumer strategies using You.i Engine-powered TV applications. You.i Engine has been licensed in major industry genres, including entertainment, kids, sports, and news. For more information about You.i TV, visit our About Page, Product Page, or take a look at the You.i TV Blog.

FOR FURTHER INFORMATION PLEASE CONTACT:

Media Contacts: Miguel Silva, CCO Vimond Media Solutions Tel: +47 951 31 604 miguel@vimond.com Trisha Cooke, VP Marketing You.i TV +1.613.608.6417 trisha.cooke@youi.tv Paul Schneider, PSPR, Inc. for You.i TV +1.215.817.4384 pspr@att.net

INDUSTRY:

Computers and Software – Hardware

SUBJECT: PRTPDT

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Media Contacts: Miguel Silva, CCO Vimond Media Solutions Tel: +47 951 31 604 miguel@vimond.com Trisha Cooke, VP Marketing You.i TV +1.613.608.6417 trisha.cooke@youi.tv Paul Schneider, PSPR, Inc. for You.i TV +1.215.817.4384 pspr@att.net}

Globenewswire

Alectra Inc. announces organizational change

April 20, 2017 by The Canadian Press

FOR: ALECTRA INC.
Date issue: April 20, 2017Time in: 1:00 PM eAttention:
MISSISSAUGA, ON –(Marketwired – April 20, 2017) – Brian Bentz, President and
Chief Executive Officer of Alectra Inc. (Alectra), announced today that Peter
Gregg, President of Al…

With a Deadline Looming, How to Choose an ELD Provider: Do Your Homework – Assetworks

June 28, 2017April 20, 2017 by EnergyNow Media

In a recent article from Truckinginfo.com, Deborah Lockridge offers insight for how to choose an electronic logging device (ELD) provider and what you need to know before ELDs become mandatory. With the ELD Mandate deadline of December 17th looming, if you haven’t begun researching ELD providers, the time is now. It may be tempting to … Read more

MGX Minerals Receives Independent Confirmation of Rapid Lithium Extraction Process

April 20, 2017 by The Canadian Press

FOR: MGX MINERALS INC.

VANCOUVER, British Columbia, April 20, 2017 (GLOBE NEWSWIRE) — MGX Minerals Inc. (“MGX” or the “Company”) (CSE:XMG) (FKT:1MG) (OTC:MGXMF) is pleased to announce it has received independent laboratory-testing results from the Saskatchewan Research Council (“SRC”) on the Company’s patent-pending “Method for Extraction of Lithium from Salt Brine” (U.S. Provisional Patent #62/419,011).

As reported by SRC, the Company’s proprietary design process was successful in recovering up to 83.7% lithium (Li) and concentrating 461 ppm Li from a 71 ppm representative sample of formation brine originating from the Sturgeon Lake oilfield.

“The results of laboratory testing by SRC provide third-party validation of our proprietary design process and its ability to rapidly separate lithium and other valuable minerals from wastewater brine,” stated MGX President and CEO Jared Lazerson. “We have made many advancements since this original process design, but this validation is important and we will continue to rely on SRC for independent testing and improvements of both active and newly developed passive filtration technologies.”

Excerpts from the SRC Summary Report- Metallurgical Tests and Executive Summary- are outlined verbatim below. Note that certain portions of the report have been redacted to protect proprietary information and data:

Table 1. Assay Results of the as Received Brine Sample

Element	K	Mg	Na	Cl	Ca	SO 2-4	Sr	Br	Li
Assay (ppm)	4212	2903	60747	116632	24753	186	1080	334	71

SRC independently carried out multi-stage evaporation tests following the patent-pending design process as provided by MGX. As reported by SRC in the executive summary:

It was not feasible to remove 90% of the water in the primary evaporation of the Formation brine because the formation of the jel-like material made the filtration impossible. The maximum water evaporation was 66% of the feed brine mass before the jel formation. Approximately 97% of Na, 26% of K, 35% of Ca and 29% of Mg were precipitated. The recovery of Li and Sr was 75.6% and 68.8%, respectively.
The modified processes including magnesium precipitation by lime followed by the primary evaporation to precipitate NaCl and the secondary evaporation to precipitate CaCl2 and concentrate lithium.
The Mg removal was very effective and more than 99.99% of Mg was removed. The residue Mg in the brine was less than 0.1 ppm. The lithium recovery was 84.1% and the Sr recovery was 80.1%.
In the primary evaporation process, 67% of the feed brine mass was evaporated as water and more than 96% of Na was removed as NaCl. There were almost no Li or Sr loss in this process. Li was concentrated from 60 ppm to 321 ppm.
In the secondary evaporation process, 26% of the feed brine mass was evaporated as water and 12% of Ca was removed as CaCl2. The lithium recovery was 94.1% and the Sr recovery was 94.6%. The sample turned to a jel-like material after further evaporation to remove 40% of the brine mass as water.
In the whole process, the estimated water evaporated was 72% of the total feed brine mass. More than 99.99% of Mg, 99% of Na, 45% of K and 25% of Ca were precipitated from the brine. The overall recovery was 83.7% for Li and 77.2% for Sr. Lithium was concentrated to 461 ppm from 71 ppm. However, the impurity level, especially Ca, was still very high and further removal of Ca through evaporation is not feasible.

SRC has provided the Company with several recommendations to remove Ca impurity levels. The full report will be filed on SEDAR within 45 days.

Qualified Person

The technical portions of this press release were prepared and reviewed by Andris Kikauka (P. Geo.), Vice President of Exploration for MGX Minerals. Mr. Kikauka is a non-independent Qualified Person within the meaning of National Instrument (N.I.) 43-101 Standards.

MGX may decide to advance its petrolithium projects into production without first establishing mineral resources supported by an independent technical report or completing a feasibility study. A production decision without the benefit of a technical report independently establishing mineral resources or reserves and any feasibility study demonstrating economic and technical viability creates increased uncertainty and heightens economic and technical risks of failure. Historically, such projects have a much higher risk of economic or technical failure.

About MGX Minerals

MGX Minerals is a diversified Canadian mining company engaged in the development of large-scale industrial mineral portfolios in western Canada and the United States. The Company operates lithium, magnesium and silicon projects throughout British Columbia and Alberta as well as petrolithium exploration in Utah. Learn more at www.mgxminerals.com.

About SRC

The Saskatchewan Research Council (SRC) is one of Canada’s leading providers of applied research, development and demonstration (RD&D) and technology commercialization. With more than 375 employees, $70 million in annual revenue and over 69 years of RD&D experience, SRC provides products and services to its 1,500 clients in 20 countries around the world.

Neither the Canadian Securities Exchange nor its Regulation Services Provider (as that term is defined in the policies of the Canadian Securities Exchange) accepts responsibility for the adequacy or accuracy of this release.

Forward-Looking Statements

This press release contains forward-looking information or forward-looking statements including the completion of the rights offering (collectively “forward-looking information”) within the meaning of applicable securities laws. Forward-looking information is typically identified by words such as: “believe”, “expect”, “anticipate”, “intend”, “estimate”, “potentially” and similar expressions, or are those, which, by their nature, refer to future events. The Company cautions investors that any forward-looking information provided by the Company is not a guarantee of future results or performance, and that actual results may differ materially from those in forward-looking information as a result of various factors. The reader is referred to the Company’s public filings for a more complete discussion of such risk factors and their potential effects which may be accessed through the Company’s profile on SEDAR at www.sedar.com.

FOR FURTHER INFORMATION PLEASE CONTACT:

Contact Information Jared Lazerson President and CEO Telephone: 1.604.681.7735 Web: www.mgxminerals.com

INDUSTRY:

Manufacturing and Production – Mining and Metals

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Contact Information Jared Lazerson President and CEO Telephone: 1.604.681.7735 Web: www.mgxminerals.com}

Globenewswire

Crescent Point Energy Announces First Quarter 2017 Conference Call and Notice of Annual General Meeting

April 20, 2017 by The Canadian Press

FOR: CRESCENT POINT ENERGY CORP.
TSX SYMBOL: CPG
NYSE SYMBOL: CPG

Date issue: April 20, 2017
Time in: 11:46 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 20, 2017) – Crescent Point Energy Corp.
(“Crescent Point” or the “Company”) (TSX:CPG) (NYSE:CPG) plans to report its
first quarter 2017 financial and operating results via news release prior to
the opening of markets on Thursday, April 27, 2017. Crescent Point management
will host a conference call at 10:00 a.m. MT (12:00 p.m. ET) on April 27, 2017,
to discuss the results and outlook for the Company.

For those unable to participate in the conference call at the scheduled time,
it will be archived for replay. You can access the replay by dialing
855-859-2056 or 404-537-3406 and entering the passcode 94659266. The replay
will be available approximately one hour following completion of the call. The
webcast will be archived on Crescent Point’s website at
www.crescentpointenergy.com.

The Company also announces that its Annual General Meeting (“AGM”) will be held
on Wednesday, May 24, 2017, at 2:00 p.m. MT (4:00 p.m. ET) in the Imperial
Ballroom of the Hyatt Regency Calgary (700 Centre Street S.E.). Shareholders
are encouraged to attend.

For those unable to attend, a webcast presentation of the Company’s AGM will
begin at approximately 2:15 p.m. MT (4:15 p.m. ET), following the conclusion of
the business portion of the meeting.

To listen to this event, please enter http://edge.media-server.com/m/p/m42z3pxa
in your web browser.

For more information about Crescent Point’s AGM please visit
www.crescentpointenergy.com/invest/agm-2017.

Crescent Point is a leading North American light and medium oil producer that
seeks to maximize shareholder return through its total return strategy of
long-term growth plus dividend income.

CRESCENT POINT ENERGY CORP.

Scott Saxberg, President and Chief Executive Officer

Crescent Point shares are traded on the Toronto Stock Exchange and New York
Stock Exchange, both under the symbol CPG.

– END RELEASE – 20/04/2017

For further information:
Crescent Point Energy Corp.
Ken Lamont
Chief Financial Officer
(403) 693-0020 or Toll-free (U.S. & Canada): 888-693-0020
(403) 693-0070 (FAX)
OR
Crescent Point Energy Corp.
Brad Borggard
Vice President, Corporate Planning and Investor Relations
(403) 693-0020 or Toll-free (U.S. & Canada): 888-693-0020
(403) 693-0070 (FAX)
www.crescentpointenergy.com

COMPANY:
FOR: CRESCENT POINT ENERGY CORP.
TSX SYMBOL: CPG
NYSE SYMBOL: CPG

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170420CC0091

Press Release from Marketwired 1-866-736-3779

TransCanada to Hold Annual Meeting of Shareholders and Issue First Quarter 2017 Financial Results on May 5

April 20, 2017 by The Canadian Press

FOR: TRANSCANADA
TSX SYMBOL: TRP
NYSE SYMBOL: TRP

Date issue: April 20, 2017
Time in: 11:00 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 20, 2017) – News Release – TransCanada
Corporation (TSX:TRP) (NYSE:TRP) (TransCanada) will hold its 2017 Annual
Meeting of Shareholders on Friday, May 5, 2017 at 10 a.m. (MDT) / 12 p.m. (EDT)
in Calgary, Alberta at the Markin MacPhail Centre at Canada Olympic Park (COP).

A live webcast of the Annual Meeting will be available at www.transcanada.com.
It will also be archived and available for replay.

Members of the media interested in attending the meeting in person are asked to
register by Friday, April 28 by calling the TransCanada Media Line at
1.800.608.7859.

First quarter 2017 financial results will also be released on May 5, 2017. Russ
Girling, TransCanada president and chief executive officer, Don Marchand,
executive vice-president and chief financial officer and other members of the
executive leadership team will host a conference call and webcast to discuss
the results and provide an update on recent company developments at 12:30 p.m.
(MDT) / 2:30 p.m. (EDT).

Members of the investment community and other interested parties are invited to
participate by calling 800.273.9672 or 416.340.2218 (Toronto area). Please dial
in 10 minutes prior to the start of the call. No pass code is required. A live
webcast of the teleconference will be available at www.transcanada.com.

A replay of the teleconference will be available two hours after the conclusion
of the call until midnight (EDT) on May 12, 2017. Please call 800.408.3053 or
905.694.9451 (Toronto area) and enter pass code 8663009.

With more than 65 years’ experience, TransCanada is a leader in the responsible
development and reliable operation of North American energy infrastructure
including natural gas and liquids pipelines, power generation and gas storage
facilities. TransCanada operates a network of natural gas pipelines that
extends more than 91,500 kilometres (56,900 miles), tapping into virtually all
major gas supply basins in North America. TransCanada is the continent’s
leading provider of gas storage and related services with 653 billion cubic
feet of storage capacity. A large independent power producer, TransCanada
currently owns or has interests in over 10,100 megawatts of power generation in
Canada and the United States. TransCanada is also the developer and operator of
one of North America’s leading liquids pipeline systems that extends over 4,300
kilometres (2,700 miles), connecting growing continental oil supplies to key
markets and refineries. TransCanada’s common shares trade on the Toronto and
New York stock exchanges under the symbol TRP. Visit TransCanada.com and our
blog to learn more, or connect with us on social media and 3BL Media.

– END RELEASE – 20/04/2017

For further information:
Media Enquiries:
Mark Cooper / James Millar
403.920.7859 or 800.608.7859
OR
TransCanada Investor & Analyst Enquiries:
David Moneta / Stuart Kampel
403.920.7911 or 800.361.6522

COMPANY:
FOR: TRANSCANADA
TSX SYMBOL: TRP
NYSE SYMBOL: TRP

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170420CC0084

Press Release from Marketwired 1-866-736-3779

Sonoco Reports First Quarter 2017 Results

April 20, 2017 by The Canadian Press

FOR: SONOCO PRODUCTS COMPANY

HARTSVILLE, S.C., April 20, 2017 (GLOBE NEWSWIRE) — Sonoco (NYSE:SON), one of the largest diversified global packaging companies, today reported financial results for its first quarter, ending April 2, 2017.

First Quarter Highlights

First quarter 2017 GAAP earnings per diluted share were $0.53, compared with $0.59 in 2016.
First quarter 2017 GAAP results included $0.06 per diluted share, after tax, in restructuring costs and acquisition-related expenses. In the first quarter of 2016, GAAP results included $0.06 per diluted share, after tax, in asset impairment and restructuring expenses.
Base net income attributable to Sonoco (base earnings) for first quarter 2017 was $0.59 per diluted share, compared with $0.65 in 2016. (See base earnings definition, explanation and reconciliation to GAAP earnings later in this release.) Sonoco previously provided first-quarter 2017 base earnings guidance of $0.55 to $0.63 per diluted share.
First-quarter 2017 net sales were $1.17 billion, down from $1.23 billion in 2016.
Cash flow from operations was $67.4 million in the first quarter of 2017, compared with $66.4 million in 2016. Free cash flow for the first quarter was a negative $18.4 million, compared with a negative $22.1 million in 2016. (See free cash flow definition and reconciliation to cash flow from operations later in this release.)
On March 14, 2017, Sonoco completed the acquisition of Peninsula Packaging Company, a leading manufacturer of thermoformed packaging for fresh fruit and vegetables based in Exeter, Calif. Sonoco acquired Peninsula Packaging for approximately $230 million, financing the transaction from a combination of available cash and a $150 million three-year term loan.

Second Quarter and Full Year Guidance Update

Base earnings for the second quarter of 2017 are estimated to be in the range of $0.67 to $0.73 per diluted share. This guidance takes into consideration the negative impact of the 2016 divestiture of the Company’s blowmolding and other smaller operations, which more than offset the current period acquisition of Peninsula Packaging and several smaller acquisitions made in 2016. Base earnings in the second quarter of 2016 were $0.73 per diluted share.
Full-year 2017 base earnings guidance has been updated to a range of $2.73 to $2.83, which includes a targeted $0.07 per diluted share expected to come from acquisitions, including Peninsula Packaging. This updated guidance is essentially unchanged from the Company’s previous guidance range of $2.66 to $2.76 per diluted share, which excluded a targeted $0.06 to $0.08 per diluted share from acquisitions and/or share repurchases.
As previously guided, 2017 operating cash flow and free cash flow are expected to be approximately $470 million and $125 million, respectively.

Note: Second-quarter and full-year 2017 GAAP guidance are not provided in this release due to the likely occurrence of one or more of the following, the timing and magnitude of which we are unable to reliably forecast: possible gains or losses on the sale of businesses or other assets, restructuring costs and restructuring-related impairment charges, acquisition-related costs, and the income tax effects of these items and/or other income tax-related events. These items could have a significant impact on the Company’s future GAAP financial results.

First Quarter ReviewCommenting on the Company’s first quarter results, Sonoco President and Chief Executive Officer Jack Sanders said, “Despite an unprecedented and unexpected sharp increase in recovered paper prices, which is the primary raw material used in our Paper and Industrial Converted Products segment, Sonoco was still able to achieve the midpoint of our first- quarter guidance. Overall, compared to the prior-year quarter, the Company’s earnings were negatively impacted by lower volume/mix; divestitures, net of acquisitions; a negative price/cost relationship; and higher labor, maintenance, pension and other operating expenses. Partially offsetting the quarter’s headwinds were procurement savings, fixed-cost productivity, lower management incentive expense, and a lower effective tax rate.

“Operating profit in our Consumer Packaging segment declined 8 percent from the prior-year quarter; however, operating margin remained at a solid 12 percent. The decline in segment operating profit was due primarily to the November 2016 sale of the Company’s blowmolding operations and lower composite can volume in Europe and North America. Segment sales declined by 9 percent, due to the divestiture of the Company’s blowmolding operations, net of acquisitions, lower volume and the negative impact of foreign exchange, partially offset by higher selling prices implemented to recover rising raw material costs and other inflation.

“Our Display and Packaging segment’s operating profit was essentially flat with last year’s quarter. Segment sales declined 21 percent primarily due to discontinuance of the Company’s contract packaging center in Mexico, which had little effect on operating profits. Results also reflect lower volume in domestic displays and retail packaging, and the negative impact of foreign exchange.

“Operating profit in our Paper and Industrial Converted Products segment declined approximately 26 percent as the average price for recovered paper in the Company’s U.S. and Canada operations increased nearly 90 percent from the prior year’s quarter, resulting in a significant negative price-cost relationship as the Company was unable to immediately pass on the higher costs to our paper, tube and core customers. Higher labor, maintenance, pension and other expenses also negatively impacted operating profit. Current-quarter segment sales grew by 5 percent due primarily to higher recovered paper prices, partially offset by the divestiture of a paperboard mill in France, lower volume and the negative impact of foreign exchange.

“Operating profit in our Protective Solutions segment declined 10 percent from the prior-year quarter, as negative volume/mix, a negative price/cost relationship, and higher labor, maintenance and other operating costs were only partially offset by fixed-cost productivity improvements. Sales improved slightly in the quarter due primarily to acquisitions.”

GAAP net income attributable to Sonoco in the first quarter was $53.7 million, or $0.53 per diluted share, compared with $59.9 million, or $0.59 per diluted share, in 2016. Base earnings in the first quarter were $59.9 million, or $0.59 per diluted share, compared with $66.5 million, or $0.65 per diluted share, in 2016. Base earnings and base earnings per diluted share are non-GAAP financial measures adjusted to remove restructuring-related items, asset impairment charges, acquisition expenses and other items, if any, the exclusion of which the Company believes improves comparability and analysis of the ongoing operating performance of the business. (See base earnings definition, explanation and reconciliation to GAAP earnings later in this release.)

First quarter GAAP earnings include after-tax restructuring costs and acquisition-related expenses of $6.1 million, or $0.06 per diluted share. In the first quarter of 2016, GAAP results included $0.06 per diluted share, after tax, in restructuring-related charges.

Net sales for the first quarter were $1.17 billion, down $54.0 million, or 4.4 percent, from last year’s quarter. The decline in sales was a result of the previously mentioned divested businesses, net of acquisitions; the discontinuation of the Company’s contract packaging business in Mexico; and the negative impact of foreign exchange, partially offset by higher selling prices, primarily attributed to rising recovered paper costs.

Gross profits were $220.2 million in the first quarter, down $25.1 million, compared with $245.3 million in the same period in 2016. Gross profit as a percent of sales declined to 18.8 percent, compared with 20.0 percent in the same period in 2016. The gross profit percentage reduction in the quarter was due primarily to an unfavorable price/cost relationship, most notably in our Industrial Segment. First-quarter selling, general and administrative expenses were down $8.1 million from the prior year at $126.1 million, driven by the previously mentioned divested businesses, net of acquisitions, lower management incentives and fewer fiscal days, partially offset by wage and other inflation.

Cash generated from operations in the first quarter was $67.4 million, compared with $66.4 million in the same period in 2016. This $1.0 million improvement was a combination of several mostly offsetting factors. Net working capital provided $65.0 million more year over year, driven by enhanced collections of items outstanding at the end of 2016 and timing of payments to suppliers. This year-over-year improvement was offset by increases in cash paid for income taxes, higher cash contributions to the Company’s pension plan, timing of various collections and payments of miscellaneous receivables and liabilities, as well as lower net income.

During the quarter, net capital expenditures were $49.0 million, compared to $53.1 million in the prior year quarter; and cash dividends paid were $36.8 million, compared to $35.4 million in the prior year.

Free cash flow for the first quarter was a negative $18.4 million, compared with a negative $22.1 million in the same quarter last year. Free cash flow is a non-GAAP financial measure which may not represent the amount of cash flow available for general discretionary use because it excludes non-discretionary expenditures, such as mandatory debt repayments and required settlements of recorded and/or contingent liabilities not reflected in cash flow from operations. (See free cash flow reconciliation later in this release. Free cash flow is defined as cash flow from operations minus net capital expenditures and cash dividends. Net capital expenditures is defined as capital expenditures minus proceeds from, and/or plus costs incurred in, the disposition of capital assets.)

At April 2, 2017, total debt was approximately $1.25 billion, compared with $1.05 billion as of December 31, 2016. At the end of the first quarter, the Company had a total debt-to-total-capital ratio of 43.8 percent, compared with 40.4 percent at December 31, 2016. Cash and cash equivalents were $212.8 million as of April 2, 2017, compared with $257.2 million at December 31, 2016. The increase in the debt ratio as well as the reduction in cash was due to the $230 million acquisition of Peninsula Packaging, which was partially financed by a new $150 million three-year term loan.

CorporateNet interest expense for the first quarter of 2017 declined to $12.1 million, compared with $13.8 million during the same period in 2016, primarily due to lower average borrowings in the current-year quarter. The 2017 first-quarter effective tax rates on GAAP and base earnings were 32.8 percent and 30.9 percent, respectively, compared with 33.2 percent and 33.0 percent, respectively, in the prior year’s quarter. The year-over-year decrease in the GAAP tax rate was due to the adoption of FASB Accounting Standards Update 2016-9 regarding accounting for share-based compensation, which requires excess tax benefits to be utilized as an offset to tax expense beginning in the 2017 period. This guidance was not retroactively applied to 2016. This benefit was mostly offset by expenses related to the settlement of an audit in Canada. The expense related to the audit settlement is a non-base item. The absence of this expense caused the change in the base rate to be more favorable year over year.

Second Quarter and Full-Year 2017 OutlookSonoco expects second-quarter 2017 base earnings to be in the range of $0.67 to $0.73 per diluted share. This guidance takes into consideration the negative impact of the previously mentioned 2016 divestitures, partially offset by the current-period acquisition of Peninsula Packaging and other acquisitions completed in 2016. Base earnings in the second quarter of 2016 were $0.73 per diluted share.

Full-year 2017 base earnings guidance is expected to be a range of $2.73 to $2.83, which includes a targeted $0.07 per diluted share expected to come from acquisitions, including Peninsula Packaging. This updated guidance is essentially unchanged from the Company’s previous guidance range of $2.66 to $2.76 per diluted share, which excluded a targeted $0.06 to $0.08 per diluted share from acquisitions and/or share repurchases. The Company’s 2017 base earnings guidance anticipates a 31.0 percent effective tax rate for the year.

Operating cash flow in 2017 is expected to be approximately $470 million, and free cash flow is expected to be approximately $125 million, each of which remains unchanged from previous guidance.

Note: Second-quarter and full-year 2017 GAAP guidance are not provided in this release due to the likely occurrence of one or more of the following, the timing and magnitude of which we are unable to reliably forecast: possible gains or losses on the sale of businesses or other assets, restructuring costs and restructuring-related impairment charges, acquisition related costs, and the income tax effects of these items and/or other income tax-related events. These items could have a significant impact on the Company’s future GAAP financial results.

Although the Company believes the assumptions reflected in the range of guidance are reasonable, given uncertainty regarding the future performance of the overall economy and potential changes in raw material prices and other costs, as well as other risks and uncertainties, including those described below, actual results could vary substantially.

Commenting on the Company’s outlook, Sanders said, “While we are starting the second quarter somewhat behind the price/cost curve, we have announced necessary price increases, along with contractual resets in nearly all of our businesses that should allow us to recover as the year progresses from the significant raw material inflation we experienced in the first quarter.

“As we manage these headwinds, we continue to be pleased with the performance of our consumer-related businesses, which accounted for nearly two-thirds of our operating profit in the quarter. We continue to see consumer demand lag for processed foods sold in the center of the store, while demand for fresh foods sold on the perimeter continues to show solid growth. Our recognition of this changing consumer behavior is exactly what led us to our recent acquisition of Peninsula Packaging. Our expansion to capture share at the perimeter of the store is just one example of how we are executing our strategy to grow our fresh and prepared food packaging offerings in thermoformed containers and flexible packaging. This broadening of our consumer portfolio offers new growth opportunities that will complement our existing innovative offerings for processed food packaging. Combined, we will significantly expand our presence at retail, as well as expanding the solutions we have to offer our customers.

“Overall, we remain optimistic for the rest of 2017. We are focused on launching new consumer-based customer initiatives, such as our new packaging center for Duracell in Atlanta, and the continued commercial expansion of our TruVue® clear can. We also are actively exploring further growth opportunities through rational, strategic acquisitions in Consumer Packaging and Protective Solutions. Finally, we will continue to look at ways to further optimize our portfolio, while aggressively pursuing new and different alternatives to improve performance in our Industrial businesses and continuing to manage our cost structure throughout the Company.”

Segment ReviewSonoco reports its financial results in four operating segments: Consumer Packaging, Display and Packaging, Paper and Industrial Converted Products, and Protective Solutions. Segment operating results do not include restructuring and asset impairment charges, acquisition expenses, interest income and expense, income taxes or certain other items, if any, the exclusion of which the Company believes improves comparability and analysis.

Consumer PackagingSonoco’s Consumer Packaging segment includes the following products and services: round and shaped rigid containers and trays (both composite and thermoformed plastic); extruded and injection-molded plastic products; printed flexible packaging; global brand artwork management; and metal and peelable membrane ends and closures.

First-quarter 2017 sales for the segment were $482 million, compared with $527 million in 2016. Segment operating profit was $58.0 million in the first quarter, compared with $62.9 million in the same quarter of 2016.

Segment sales declined 8.6 percent compared to the prior-year quarter due to the divestiture of the Company’s blowmolding operations, net of acquisitions, lower volume and the negative impact of foreign exchange, partially offset by higher selling prices. Segment operating profit decreased 7.7 percent over the prior-year quarter due to the sale of the blowmolding operations, net of acquisitions, and lower composite can volume in Europe and North America. In addition, results were negatively impacted by higher labor, maintenance, pension and other operating expenses. Partially offsetting these negative factors were fixed-cost productivity improvements and a positive price/cost relationship.

Display and PackagingThe Display and Packaging segment includes the following products and services: designing, manufacturing, assembling, packing and distributing temporary, semi-permanent and permanent point-of-purchase displays; supply chain management services, including contract packing, fulfillment and scalable service centers; retail packaging, including printed backer cards, thermoformed blisters and heat sealing equipment; and paper amenities, such as coasters and glass covers.

First quarter 2017 sales for this segment were $115 million, compared with $144 million in 2016. Segment operating profit was $3.2 million in the quarter, compared with $3.3 million in the prior-year quarter.

Sales declined 20.5 percent compared to last year’s quarter due primarily to the discontinuance of the Company’s contract packaging center in Mexico, lower volume in domestic displays and retail packaging, and the negative impact of foreign exchange. Operating profit in the segment was essentially flat year over year, as negative volume/mix in domestic display and retail packaging was nearly offset by fixed-cost productivity.

Paper and Industrial Converted ProductsThe Paper and Industrial Converted Products segment includes the following products: paperboard tubes and cores; fiber-based construction tubes; wooden, metal and composite wire and cable reels and spools; and recycled paperboard, linerboard, corrugating medium, recovered paper and material recycling services.

First-quarter 2017 sales for the segment were $443 million, up from $423 million in 2016. Segment operating profit was $24.7 million in the first quarter, compared with $33.3 million in 2016.

Segment sales grew approximately 4.6 percent during the quarter due to higher recovered paper prices, partially offset by the divestiture of a paperboard mill in France, lower volume and the negative impact of foreign exchange. Segment operating profit declined 25.8 percent compared to the prior year quarter due to a negative price/cost relationship and higher labor, maintenance, pension and other operating expenses.

Protective SolutionsThe Protective Solutions segment includes the following products: custom-engineered, paperboard-based and expanded foam protective packaging and components; and temperature-assured packaging.

First quarter 2017 sales were $133 million, compared with $132 million in 2016. Operating profit was $10.9 million, compared with $12.0 million in the first quarter of 2016.

This segment’s 1.1 percent increase in first quarter sales came from acquisitions and was partially offset by negative volume/mix. Operating profit was down 9.7 percent in the quarter, as negative volume/mix and price/cost were partially offset by fixed-cost productivity improvement.

Conference Call WebcastManagement will host a conference call and webcast to further discuss these results beginning at 11 a.m. ET today. The live conference call and a corresponding presentation can be accessed via the Internet at www.sonoco.com, under the Investor Relations section, or at http://investor.sonoco.com. A telephonic replay of the call will be available starting at 2 p.m. ET, to U.S. callers at 855-859-2056 and international callers at +404-537-3406. The replay passcode for both U.S. and international calls is 3220993. The archived call will be available through April 30, 2017. The webcast call also will be archived in the Investor Relations section of Sonoco’s website.

About SonocoFounded in 1899, Sonoco is a global provider of a variety of consumer packaging, industrial products, protective packaging, and displays and packaging supply chain services. With annualized net sales of approximately $4.8 billion, the Company has 20,000 employees working in more than 300 operations in 33 countries, serving some of the world’s best known brands in some 85 nations. For more information on the Company, visit our website at www.sonoco.com.

Forward-looking StatementsStatements included herein that are not historical in nature, are intended to be, and are hereby identified as “forward-looking statements” for purposes of the safe harbor provided by Section 21E of the Securities Exchange Act of 1934, as amended. In addition, the Company and its representatives may from time to time make other oral or written statements that are also “forward-looking statements.” Words such as “estimate,” “project,” “intend,” “expect,” “believe,” “consider,” “plan,” “strategy,” “opportunity,” “commitment,” “target,” “anticipate,” “objective,” “goal,” “guidance,” “outlook,” “forecast,” “future,” “re-envision, ” “assume,” “will,” “would,” “can,” “could,” “may,” “might,” “aspires,” “potential,” or the negative thereof, and similar expressions identify forward-looking statements.

Forward-looking statements include, but are not limited to, statements regarding: availability and supply of raw materials, and offsetting high raw material costs; improved productivity and cost containment; improving margins and leveraging strong cash flow and financial position; effects of acquisitions and dispositions; realization of synergies resulting from acquisitions; costs, timing and effects of restructuring activities; adequacy and anticipated amounts and uses of cash flows; expected amounts of capital spending; refinancing and repayment of debt; financial strategies and the results expected of them; financial results for future periods; producing improvements in earnings; profitable sales growth and rates of growth; market leadership; research and development spending; extent of, and adequacy of provisions for, environmental liabilities; adequacy of income tax provisions, realization of deferred tax assets, outcomes of uncertain tax issues and tax rates; goodwill impairment charges and fair values of reporting units; future asset impairment charges and fair values of assets; anticipated contributions to pension and postretirement benefit plans, fair values of plan assets, long-term rates of return on plan assets, and projected benefit obligations and payments; creation of long-term value and returns for shareholders; continued payment of dividends; and planned stock repurchases.

Such forward-looking statements are based on current expectations, estimates and projections about our industry, management’s beliefs and certain assumptions made by management. Such information includes, without limitation, discussions as to guidance and other estimates, perceived opportunities, expectations, beliefs, plans, strategies, goals and objectives concerning our future financial and operating performance. These statements are not guarantees of future performance and are subject to certain risks, uncertainties and assumptions that are difficult to predict.

Therefore, actual results may differ materially from those expressed or forecasted in such forward-looking statements. The risks, uncertainties and assumptions include, without limitation:

availability and pricing of raw materials, energy and transportation, and the Company’s ability to pass raw material, energy and transportation price increases and surcharges through to customers or otherwise manage these commodity pricing risks;
costs of labor;
work stoppages due to labor disputes;
success of new product development, introduction and sales;
consumer demand for products and changing consumer preferences;
ability to be the low-cost global leader in customer-preferred packaging solutions within targeted segments;
competitive pressures, including new product development, industry overcapacity, and changes in competitors’ pricing for products;
ability to maintain or increase productivity levels, contain or reduce costs, and maintain positive price/cost relationships;
ability to negotiate or retain contracts with customers, including in segments with concentration of sales volume;
ability to improve margins and leverage cash flows and financial position;
continued strength of our paperboard-based tubes and cores and composite can operations;
ability to manage the mix of business to take advantage of growing markets while reducing cyclical effects of some of the Company’s existing businesses on operating results;
ability to maintain innovative technological market leadership and a reputation for quality;
ability to profitably maintain and grow existing domestic and international business and market share;
ability to expand geographically and win profitable new business;
ability to identify and successfully close suitable acquisitions at the levels needed to meet growth targets, and successfully integrate newly acquired businesses into the Company’s operations;
the costs, timing and results of restructuring activities;
availability of credit to us, our customers and suppliers in needed amounts and on reasonable terms;
effects of our indebtedness on our cash flow and business activities;
fluctuations in obligations and earnings of pension and postretirement benefit plans;
accuracy of assumptions underlying projections of benefit plan obligations and payments, valuation of plan assets, and projections of long-term rates of return;
cost of employee and retiree medical, health and life insurance benefits;
resolution of income tax contingencies;
foreign currency exchange rate fluctuations, interest rate and commodity price risk and the effectiveness of related hedges;
changes in U.S. and foreign tax rates, and tax laws, regulations and interpretations thereof;
accuracy in valuation of deferred tax assets;
accuracy of assumptions underlying projections related to goodwill impairment testing, and accuracy of management’s assessment of goodwill impairment;
accuracy of assumptions underlying fair value measurements, accuracy of management’s assessments of fair value and fluctuations in fair value;
liability for and anticipated costs of environmental remediation actions;
effects of environmental laws and regulations;
operational disruptions at our major facilities;
failure or disruptions in our information technologies;
loss of consumer or investor confidence;
ability to protect our intellectual property rights;
actions of domestic or foreign government agencies and changes in laws and regulations affecting the Company;
international, national and local economic and market conditions and levels of unemployment; and
economic disruptions resulting from terrorist activities and natural disasters.

The Company undertakes no obligation to publicly update or revise forward-looking statements, whether as a result of new information, future events or otherwise. In light of these risks, uncertainties and assumptions, the forward-looking events discussed herein might not occur.

Additional information concerning some of the factors that could cause materially different results is included in the Company’s reports on forms 10-K, 10-Q and 8-K filed with the Securities and Exchange Commission. Such reports are available from the Securities and Exchange Commission’s public reference facilities and its website, sec.gov, and from the Company’s investor relations department and the Company’s website, www.sonoco.com.

References to our Website AddressReferences to our website address and domain names throughout this release are for informational purposes only, or to fulfill specific disclosure requirements of the Securities and Exchange Commission’s rules or the New York Stock Exchange Listing Standards. These references are not intended to, and do not, incorporate the contents of our website by reference into this release.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited)
(Dollars and shares in thousands except per share)

	Three Months Ended
	April 2, 2017			April 3, 2016

Net sales	$	1,172,324		$	1,226,276
Cost of sales	952,102			981,023
Gross profit	220,222			245,253
Selling, general and administrative expenses	126,138			134,193
Restructuring/Asset impairment charges	4,111			9,228
Income before interest and income taxes	$	89,973		$	101,832
Net interest expense	12,058			13,787
Income before income taxes	77,915			88,045
Provision for income taxes	25,539			29,194
Income before equity in earnings of affiliates	52,376			58,851
Equity in earnings of affiliates, net of tax	1,954			1,339
Net income	54,330			60,190
Net income attributable to noncontrolling interests	(597		)	(276		)
Net income attributable to Sonoco	$	53,733		$	59,914

Weighted average common shares outstanding – diluted	100,980			102,329

Diluted earnings per common share	$	0.53		$	0.59
Dividends per common share	$	0.37		$	0.35

FINANCIAL SEGMENT INFORMATION (Unaudited)
(Dollars in thousands)

		Three Months Ended
		April 2, 2017			April 3, 2016
Net sales
	Consumer Packaging	$	482,181		$	527,338
	Display and Packaging	114,635			144,267
	Paper and Industrial Converted Products	442,502			423,074
	Protective Solutions	133,006			131,597
	Consolidated	$	1,172,324		$	1,226,276

Income before interest and income taxes:
Segment operating profit:
	Consumer Packaging	$	58,010		$	62,865
	Display and Packaging	3,183			3,281
	Paper and Industrial Converted Products	24,723			33,299
	Protective Solutions	10,861			12,026
	Restructuring/Asset impairment charges	(4,111		)	(9,228		)
	Other, net	(2,693		)	(411		)
	Consolidated	$	89,973		$	101,832

CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited)
(Dollars in thousands)

	Three Months Ended
	April 2, 2017			April 3, 2016
Net income	$	54,330		$	60,190
Asset impairment charges	337			—
Depreciation, depletion and amortization	49,008			53,572
Net pension and postretirement plan expenses/(contributions)	(31,204		)	(21,385		)
Changes in working capital	(5,070		)	(70,054		)
Other operating activity	(3		)	44,064
Net cash provided by operating activities	67,398			66,387

Purchase of property, plant and equipment, net	(48,974		)	(53,093		)
Cost of acquisitions, net of cash acquired	(221,417		)	—
Net debt proceeds/(repayments)	193,660			2,794
Cash dividends	(36,840		)	(35,396		)
Shares acquired under announced buyback	—			(15,318		)
Other, including effects of exchange rates on cash	1,737			4,530

Net increase/(decrease) in cash and cash equivalents	(44,436		)	(30,096		)
Cash and cash equivalents at beginning of period	$	257,226		$	182,434
Cash and cash equivalents at end of period	$	212,790		$	152,338

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)
(Dollars in thousands)
		April 2, 2017		December 31, 2016
Assets
Current Assets:
	Cash and cash equivalents	$	212,790	$	257,226
	Trade accounts receivable, net of allowances	663,312		625,411
	Other receivables	43,003		43,553
	Inventories	430,359		372,814
	Prepaid expenses and deferred income taxes	41,831		49,764
		1,391,295		1,348,768
Property, plant and equipment, net		1,155,192		1,060,017
Goodwill		1,156,674		1,092,215
Other intangible assets, net		273,894		224,958
Other assets		213,350		197,245
		$	4,190,405	$	3,923,203
Liabilities and Shareholders’ Equity
Current Liabilities:
	Payable to suppliers and other payables	$	787,602	$	751,827
	Notes payable and current portion of long-term debt	76,712		32,045
	Income taxes payable	18,086		18,744
		$	882,400	$	802,616
Long-term debt, net of current portion		1,177,188		1,020,698
Pension and other postretirement benefits		419,180		447,339
Deferred income taxes and other		102,770		97,845
Total equity		1,608,867		1,554,705
		$	4,190,405	$	3,923,203

Definition and Reconciliation of Non-GAAP Financial Measures

The Company’s results determined in accordance with U.S. generally accepted accounting principles (GAAP) are referred to as “as reported” or “GAAP” results. Some of the information presented in this press release reflects the Company’s “as reported” or “GAAP” results adjusted to exclude amounts related to restructuring initiatives, asset impairment charges, environmental charges, acquisition costs, excess insurance recoveries, losses from the early extinguishment of debt, and certain other items, if any, the exclusion of which management believes improves comparability and analysis of the ongoing operating performance of the business. These adjustments result in the non-GAAP financial measures referred to in this press release as “Base Earnings” and “Base Earnings per Diluted Share.”

These non-GAAP measures are not in accordance with, or an alternative for, generally accepted accounting principles and may be different from non-GAAP measures used by other companies. In addition, these non-GAAP measures are not based on any comprehensive set of accounting rules or principles. Sonoco continues to provide all information required by GAAP, but it believes that evaluating its ongoing operating results may not be as useful if an investor or other user is limited to reviewing only GAAP financial measures. Sonoco uses these non-GAAP financial measures for internal planning and forecasting purposes, to evaluate its ongoing operations, and to evaluate the ultimate performance of each business unit against budget all the way up through the evaluation of the Chief Executive Officer’s performance by the Board of Directors. In addition, these same non-GAAP measures are used in determining incentive compensation for the entire management team and in providing earnings guidance to the investing community.

Sonoco management does not, nor does it suggest that investors should, consider these non-GAAP financial measures in isolation from, or as a substitute for, financial information prepared in accordance with GAAP. Sonoco presents these non-GAAP financial measures to provide users information to evaluate Sonoco’s operating results in a manner similar to how management evaluates business performance. Material limitations associated with the use of such measures are that they do not reflect all period costs included in operating expenses and may not reflect financial results that are comparable to financial results of other companies that present similar costs differently. Furthermore, the calculations of these non-GAAP measures are based on subjective determinations of management regarding the nature and classification of events and circumstances that the investor may find material and view differently.

To compensate for these limitations, management believes that it is useful in understanding and analyzing the results of the business to review both GAAP information which includes all of the items impacting financial results and the non-GAAP measures that exclude certain elements, as described above. Whenever Sonoco uses a non-GAAP financial measure, except with respect to guidance, it provides a reconciliation of the non-GAAP financial measure to the most closely applicable GAAP financial measure. Whenever reviewing a non-GAAP financial measure, investors are encouraged to fully review and consider the related reconciliation as detailed below. Second-quarter and full-year 2017 GAAP guidance are not provided in this release due to the likely occurrence of one or more of the following, the timing and magnitude of which we are unable to reliably forecast: possible gains or losses on the sale of businesses or other assets, restructuring costs and restructuring-related impairment charges, acquisition related costs, and the income tax effects of these items and/or other income tax-related events. These items could have a significant impact on the Company’s future GAAP financial results.

				Non-GAAP Adjustments
Three Months Ended April 2, 2017	GAAP			Restructuring / Asset Impairment Charges(1)			Other Adjustments(2)			Base

Income before interest and income taxes	89,973			4,111			2,693			96,777
Interest expense, net	12,058			—			—			12,058
Income before income taxes	77,915			4,111			2,693			84,719
Provision for income taxes	25,539			1,298			(641		)	26,196
Income before equity in earnings of affiliates	52,376			2,813			3,334			58,523
Equity in earnings of affiliates, net of taxes	1,954			—			—			1,954
Net income	54,330			2,813			3,334			60,477
Net (income) attributable to noncontrolling interests	(597		)	(2		)	—			(599		)
Net income attributable to Sonoco	$	53,733		$	2,811		$	3,334		$	59,878

Per Diluted Share	$	0.53		$	0.03		$	0.03		$	0.59


				Non-GAAP Adjustments
Three Months Ended April 3, 2016	GAAP			Restructuring / Asset Impairment Charges(1)			Other Adjustments(3)			Base

Income before interest and income taxes	101,832			9,228			411			111,471
Interest expense, net	13,787			—			—			13,787
Income before income taxes	88,045			9,228			411			97,684
Provision for income taxes	29,194			2,920			104			32,218
Income before equity in earnings of affiliates	58,851			6,308			307			65,466
Equity in earnings of affiliates, net of taxes	1,339			—			—			1,339
Net income	60,190			6,308			307			66,805
Net (income) attributable to noncontrolling interests	(276		)	(7		)	—			(283		)
Net income attributable to Sonoco	$	59,914		$	6,301		$	307		$	66,522

Per Diluted Share	$	0.59		$	0.06		$	—		$	0.65

(1) Restructuring/Asset impairment charges are a recurring item as Sonoco’s restructuring programs usually require several years to fully implement and the Company is continually seeking to take actions that could enhance its efficiency. Although recurring, these charges are subject to significant fluctuations from period to period due to the varying levels of restructuring activity and the inherent imprecision in the estimates used to recognize the impairment of assets and the wide variety of costs and taxes associated with severance and termination benefits in the countries in which the restructuring actions occur.

(2)Consists primarily of costs related to acquisitions and potential acquisitions which were partially offset by insurance settlement gains. Additionally, includes non-base tax charges related to settlement of an income tax audit in Canada.

(3)Consists primarily of costs related to acquisitions and potential acquisitions.

	Three Months Ended
FREE CASH FLOW*	April 2, 2017			April 3, 2016

Net cash provided by operating activities	$	67,398		$	66,387
Purchase of property, plant and equipment, net	(48,974		)	(53,093		)
Cash dividends	(36,840		)	(35,396		)
Free Cash Flow	$	(18,416	)	$	(22,102	)


	Twelve Months Ended
	Estimated			Actual
FREE CASH FLOW*	December 31, 2017			December 31, 2016
Net cash provided by operating activities	$	470,000		$	398,679
Purchase of property, plant and equipment, net	(191,000		)	(186,741		)
Cash dividends	(154,000		)	(146,364		)
Free Cash Flow	$	125,000		$	65,574


* Free Cash Flow is a non-GAAP measure that does not imply the amount of residual cash flow available for discretionary expenditures, as it excludes mandatory debt service requirements and other non-discretionary expenditures.

FOR FURTHER INFORMATION PLEASE CONTACT:

Contact: Roger Schrum +843-339-6018 roger.schrum@sonoco.com

INDUSTRY:

Manufacturing and Production – Packaging and Containers

SUBJECT: ERN

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Contact: Roger Schrum +843-339-6018 roger.schrum@sonoco.com}

Globenewswire

Urban Communications Inc. Reports Record Revenue in Q1 2017

April 20, 2017 by The Canadian Press

FOR: URBAN COMMUNICATIONS INC.

VANCOUVER, British Columbia, April 20, 2017 (GLOBE NEWSWIRE) — Urban Communications Inc. (TSX-V:UBN) one of the country’s first telecommunications companies to deliver Gigabit Internet service to the home, today announced preliminary financial results and a record increase in revenue for the month of March 2017 and the three month period ending March 31, 2017. Financial results for the three month period ending March 31, 2017, will be released in May 2017. The information contained herein may change based on final results.

Highlights:

March revenue reached an all time high of $268,000
First quarter 2017 revenue saw a 32% increase over the three months ending Dec 31, 2016
First quarter 2017 revenue saw a 190% increase over the same period in 2016.

Revenue increase during the period is primarily attributable to strong growth in Urban’s commercial service offering which represented 80% of the first quarter’s revenue. Financial results for the three month period ending March 31, 2017, will be released in May 2017. The information contained herein may change based on final results.

“Our current revenue growth is a direct result of the success of our sales team in growing our sales funnel,” said John Farlinger, Urban CEO. “We continue to focus on new monthly recurring revenue opportunities in our commercial segment, particularly in the downtown core.”

Urban’s carrier grade fibre optic network is the ultimate choice in high performance and reliable data network services for any business. With the most competitive pricing, the highest speeds and data transfer limits on Internet plans, guaranteed SLAs, and a legacy-free, congestion-free network architecture, our Internet, Ethernet, private and managed MPLS network services are the best performing services in our market.

For more information about Urbanfibre Gigabit Internet for business or residential customers, please visit www.urbanfibre.ca.

ABOUT URBAN COMMUNICATIONS INC.

Urban Communications Inc. (TSX-V:UBN) is a telecommunications company providing a full suite of Internet, voice, video and broadband application products over its 300 km. state-of-the-art carrier grade fibre optic network in Metro Vancouver and Victoria to commercial, residential and public sector customers. Urban has recently launched high-speed Internet service to residential and commercial subscribers on its network at 1,000 Mbps (1 Gbps).

Neither TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.

FOR FURTHER INFORMATION PLEASE CONTACT:

CONTACT INFO: John Farlinger, Chief Executive Officer Phone: (604) 763-7565 jafarlinger@urbanfibre.ca

INDUSTRY:

Telecom – Telecommunication Services

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: CONTACT INFO: John Farlinger, Chief Executive Officer Phone: (604) 763-7565 jafarlinger@urbanfibre.ca}

Globenewswire

James Hyland Joins Stamper Oil & Gas as Vice President of Business Development

April 20, 2017 by The Canadian Press

FOR: STAMPER OIL & GAS CORP.

VANCOUVER, British Columbia, April 20, 2017 (GLOBE NEWSWIRE) — Stamper Oil & Gas Corp. (TSX.V:STMP) (OTC Markets:AZUEF) (FSE:TMP2) (“Stamper” or “the Company”), is pleased to announce that James Hyland has been named Vice President of Business Development for Stamper. James will report to David Greenway, President, and will be responsible for communications strategy and implementation of new business opportunities.

James joins Stamper with more than 25 years of experience as a financial and marketing consultant, a corporate founder and manager of a number of early stage public and private Canadian businesses. His industry expertise includes hospitality, publishing, financial services, oil & gas, technology, mining, alternative energy and healthcare appliances. Mr. Hyland has an extensive network of contacts within the financial community including brokers, fund managers, industry analysts and media, throughout North America, the United Kingdom and continental Europe. Mr. Hyland has also worked with a major mining and resource publication based in Vancouver, BC.

Mr. Hyland earned a Bachelor of Commerce in Entrepreneurial Management from Royal Roads University of Victoria, BC, Canada.

David Greenway states, “Jamie brings to Stamper great interpersonal and networking skills and we are very excited to have him as part of the Stamper team. His business acumen and diversification of experience across many communication disciplines will be a great asset to assist on developing clear message and bringing shareholder value to the company.”

About Stamper Oil & Gas

Stamper Oil & Gas Corp. is an independent international oil and gas company, engaged in the acquisition, exploration and development of conventional oil and natural gas properties. The Company plans to identify and build out a portfolio of high-impact oil and gas prospects, with a focus on Latin America. Stamper is committed to creating sustainable shareholder value by evaluating and developing future prospects into commercially viable assets.

For further information on Stamper Oil & Gas Corp. please visit www.stamperoilandgas.com

ON BEHALF OF THE BOARD OF DIRECTORS

“David C. Greenway”President & Director

Neither TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.

Forward-Looking Statements

This news release contains certain statements that may be deemed “forward-looking” statements. Forward looking statements are statements that are not historical facts and are generally, but not always, identified by the words “expects”, “plans”, “anticipates”, “believes”, “intends”, “estimates”, “projects”, “potential” and similar expressions, or that events or conditions “will”, “would”, “may”, “could” or “should” occur. Although Stamper Oil and Gas Corp. believes the expectations expressed in such forward-looking statements are based on reasonable assumptions, such statements are not guarantees of future performance and actual results may differ materially from those in forward looking statements. Forward looking statements are based on the beliefs, estimates and opinions of Stamper Oil and Gas Corp. management on the date the statements are made. Except as required by law, Stamper Oil and Gas Corp undertakes no obligation to update these forward-looking statements in the event that management’s beliefs, estimates or opinions, or other factors, should change.

FOR FURTHER INFORMATION PLEASE CONTACT:

For further information, please contact: Stamper Oil & Gas Corp. Investor Relations Phone: (604) 684-2401 Email: ir@stamperoilandgas.com

INDUSTRY:

Miscellaneous – Miscellaneous

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: For further information, please contact: Stamper Oil & Gas Corp. Investor Relations Phone: (604) 684-2401 Email: ir@stamperoilandgas.com}

Globenewswire

TransCanada Announces Completed Sale of New England Hydro Assets

April 20, 2017 by The Canadian Press

FOR: TRANSCANADA
TSX SYMBOL: TRP
NYSE SYMBOL: TRP

Date issue: April 20, 2017
Time in: 8:00 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 20, 2017) – News Release – TransCanada
Corporation (TSX:TRP) (NYSE:TRP) (TransCanada) today announced that it has
completed the sale of its hydroelectric generation assets to Great River Hydro,
LLC, an affiliate of ArcLight Capital Partners, LLC for US $1.065 billion.

The sale includes 13 hydroelectric facilities, stations and associated dams and
reservoirs on the Connecticut and Deerfield Rivers. The assets are located in
New Hampshire, Vermont and Massachusetts with a total generating capacity of
584 megawatts.

Proceeds from the sale of these facilities will be used to repay debt financing
raised to fund the 2016 Columbia Pipeline Group acquisition, which created one
of North America’s largest regulated natural gas transmission companies.

FORWARD LOOKING INFORMATION

This publication contains certain information that is forward-looking and is
subject to important risks and uncertainties (such statements are usually
accompanied by words such as “anticipate”, “expect”, “believe”, “may”, “will”,
“should”, “estimate”, “intend” or other similar words). Forward-looking
statements in this document are intended to provide TransCanada security
holders and potential investors with information regarding TransCanada and its
subsidiaries, including management’s assessment of TransCanada’s and its
subsidiaries’ future plans and financial outlook. All forward-looking
statements reflect TransCanada’s beliefs and assumptions based on information
available at the time the statements were made and as such are not guarantees
of future performance. Readers are cautioned not to place undue reliance on
this forward-looking information, which is given as of the date it is expressed
in this news release, and not to use future-oriented information or financial
outlooks for anything other than their intended purpose. TransCanada undertakes
no obligation to update or revise any forward-looking information except as
required by law. For additional information on the assumptions made, and the
risks and uncertainties which could cause actual results to differ from the
anticipated results, refer to the Quarterly Report to Shareholders dated
February 16, 2017 and 2016 Annual Report filed under TransCanada’s profile on
SEDAR at www.sedar.com and with the U.S. Securities and Exchange Commission at
www.sec.gov.

– END RELEASE – 20/04/2017

For further information:
Media Enquiries:
Terry Cunha / Mark Cooper
403.920.7859 or 800.608.7859
OR
TransCanada Investor & Analyst Enquiries:
David Moneta / Stuart Kampel
403.920.7911 or 800.361.6522

COMPANY:
FOR: TRANSCANADA
TSX SYMBOL: TRP
NYSE SYMBOL: TRP

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170420CC0039

Press Release from Marketwired 1-866-736-3779

Mariana Resources Ltd : Audited Annual Financial Statements and Management Discussion and Analysis for the Year Ended 31 Decembe

April 20, 2017 by The Canadian Press

FOR: MARIANA RESOURCES LTD.

AIM: MARLTSXV: MARL 20 April 2017

Granite House, La Grande Rue,St. Martin, Guernsey, GY1 3RS Channel Islands

THIS NEWS RELEASE IS NOT FOR DISTRIBUTION TO THE UNITED STATES NEWSWIRE SERVICES OR FOR DISSEMINATION IN THE UNITED STATES.

Mariana Resources Limited has released its audited annual financial statements and annual report as well as the Management Discussion and Analysis for the year ended 31 December 2016.

The following documents may be obtained by clicking the attachment or on the link below or via the Company’s web site (www.marianaresources.com) and will be filed on SEDAR:

Annual Report Link: http://docs.wixstatic.com/ugd/24ee23_a1a5dbc1e15d40e489e711da2bad29f9.pdf

MD&A Link: http://media.wix.com/ugd/24ee23_22ef8b554fb14acb98db02781586dd8e.pdf

MARIANA RESOURCES LTD.“Glen Parsons”Glen Parsons, Chief Executive Officer

ENDS

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.

For further information please visit website at www.marianaresources.com or contact the following.


Glen Parsons (CEO)	Mariana Resources Ltd	+61 2 9437 4588
Eric Roth (COO)	Mariana Resources Ltd	+56 9 8818 1243
Karen Davies (IR)	Mariana Resources Ltd (Canada)	+1 604 314 6270
Rob Adamson	RFC Ambrian Limited (Nomad)	+61 2 9250 0041
Will Souter	RFC Ambrian Limited (Nomad)	+61 2 9250 0050
In U.K.
Oliver Stansfield	Brandon Hill Capital (UK Broker)	+44 20 3463 5061
Jonathan Evans	Brandon Hill Capital (UK Broker)	+44 20 3463 5016
Camilla Horsfall	Blytheweigh (Financial PR)	+44 20 7138 3224
Megan Ray	Blytheweigh (Financial PR)	+44 20 7138 3203

About Mariana ResourcesMariana Resources Ltd is a TSX.V and AIM (MARL) quoted exploration and development company with an extensive portfolio of gold, silver, and copper projects in South America, Turkey, and Ivory Coast.

Mariana’s most advanced asset is the Hot Maden gold-copper project in northeast Turkey, which is a joint venture with Turkish partner Lidya Madencilik (30% Mariana and 70% Lidya) and which is rapidly advancing to development. On January 17, 2017, Mariana released the results of a Preliminary Economic Study (“PEA”) which demonstrated exceptional potential economics for the Hot Maden Project (after-tax NPV and IRR of USD 1.37B and 153%, respectively) based on a development scenario incorporating a 1Mtpa underground mining / processing operation and the production of two saleable concentrates (a copper-gold concentrate and a gold-pyrite concentrate). This PEA was based on the updated (July 25, 2016) mineral resource estimate of 3.43 Moz gold equivalent (Indicated Category) and 0.09 Moz gold equivalent (Inferred Category) (100% basis) in the Main Zone, as well as a maiden 351,000 Moz gold equivalent (Inferred Category) (100% basis) resource in the New Southern Discovery. Elsewhere in Turkey, Mariana holds a 100% interest in the Ergama gold-copper project.

On October 7, 2016, Mariana announced the signing of a binding Term Sheet to acquire an indirect 80% interest in Ivory Coast-focused private exploration company Awalé Resources SARL (“Awalé”). Through the transaction Mariana will gain an immediate foothold in an established exploration portfolio with known gold mineralisation and artisanal gold workings, and which comprises i) 3 granted contiguous licenses (1,191 km2) in the Bondoukou area, and ii) 4 licenses under application (1,593 km2) in both the Bondoukou and Abengourou areas. The Boundoukou concessions lie along the southwestern extension of the Birimian Bole-Nangodi greenstone belt in adjacent Ghana, host to a number of high grade orogenic gold deposits.

In southern Argentina, the Company’s core gold-silver projects are Las Calandrias (100%), Sierra Blanca (100%), Los Cisnes (100%), and Bozal (100%). These projects are part of a 100,000+ Ha land package in the Deseado Massif epithermal gold-silver district in mining-friendly Santa Cruz Province.

In Suriname, Mariana has a direct holding of 10.2% of the Nassau Gold project. The Nassau Gold Project is a 28,000 Ha exploration concession located approximately 125 km south east of the capital Paramaribo and immediately adjacent to Newmont Mining’s 4.2Moz gold Merian project.

In Peru and Chile, Mariana is focusing on acquiring new opportunities which complement its current portfolio.

	Hot Maden Mineral Resource Estimate – Main Gold-Copper Zone (2 g/t AuEq Cut-off)
			Indicated Mineral Resource
Domain		Tonnes		Au	Cu	Zn	AuEq	Au	Cu	AuEq
		t		g/t	%	%	g/t*	Ounces	Tonnes	Ounces**
Main Zone LG		463,000		1.1	1.1	0.3	2.4	17,000	5,000	36,000
Main Zone HG		4,501,000		3.9	1.9	0.2	6.3	570,000	87,000	908,000
Main Zone UHG		2,086,000		32.7	3.5	0.1	36.9	2,195,000	73,000	2,476,000
Mixed Gold-Zinc		17,000		7.5	3.1	3.6	11.2	4,000	1,000	6,000
Peripheral Lodes		60,000		2.1	0.4	0.4	2.5	4,000		5,000
Total		7,127,000		12.2	2.3	0.2	15.0	2,790,000	166,000	3,431,000
			Inferred Mineral Resource
Domain		Tonnes		Au	Cu	Zn	AuEq	Au	Cu	AuEq
		t		g/t	%	%	g/t*	Ounces	Tonnes	Ounces**
Main Zone LG		395,000		1.7	0.9	0.03	2.8	21,000	4,000	35,000
Main Zone HG		31,000		3.9	1.6	0.1	5.8	4,000		6,000
Main Zone UHG		6,000		39.1	2.1	0.01	41.6	7,000		8,000
Mixed Gold-Zinc		4,000		1.7	0.4	2.4	2.2
Peripheral Lodes		282,000		3.2	0.9	0.1	4.3	29,000	2,000	38,000
Total		718,000		2.7	0.9	0.1	3.8	62,000	7,000	88,000
	Hot Maden – Southern Gold-Copper Zone (2 g/t AuEq Cut-off)
			Inferred Mineral Resource
Domain		Tonnes		Au	Cu	Zn	AuEq	Au	Cu	AuEq
		t		g/t	%	%	g/t*	Ounces	Tonnes	Ounces**
South Zone LG		396,000		2.8	0.7	0.0	3.6	35,000	3,000	46,000
South Zone HG		583,000		5.3	0.7	0.0	6.1	98,000	4,000	114,000
Main Zone UHG		224,000		22.2	1.0	0.0	23.4	160,000	2,000	169,000
Mixed Gold-Zinc		44,000		9.0	1.0	3.2	10.2	13,000		15,000
Peripheral Lodes		104,000		1.9	0.3	0.0	2.2	6,000		7,000
Total		1,352,000		7.2	0.7	0.1	8.1	313,000	10,000	351,000

*Au Equivalence (AuEq) calculated using a 100 day moving average of $US1,215/ounce for Au and $US2.13/pound for Cu as of May 29, 2016. No adjustment has been made for metallurgical recovery or net smelter return as these remain uncertain at this time. Based on grades and contained metal for Au and Cu, it is assumed that both commodities have reasonable potential to be economically extractable.

*-The formula used for Au equivalent grade is: AuEq g/t = Au + [(Cu % x 22.0462 x 2.13)/(1215/31.1035)] and assumes 100 % metallurgical recovery.
**-Au equivalent ounces are calculated by mulitplying Mineral Resource tonnage by Au equivalent grade and converting for ounces. The formula used for Au equivalent ounces is: AuEq Oz = [Tonnage x AuEq grade (g/t)]/31.1035

Safe HarbourThis press release contains certain statements which may be deemed to be forward-looking statements. These forward-looking statements are made as at the date of this press release and include, without limitation, statements regarding discussions of future plans, the realization, cost, timing and extent of mineral resource estimates, estimated future exploration expenditures, costs and timing of the development of new deposits, success of exploration activities, permitting time lines, and requirements for additional capital. The words “plans”, “expects”, “budget”, “scheduled”, “estimate”, “forecasts”, “intend”, “anticipate”, “believe”, “may”, “will”, or similar expressions or variations of such words are intended to identify forward-looking statements. Forward-looking statements are subject to known and unknown risks, uncertainties, assumptions and other factors that may cause actual results to vary materially from those expressed or implied by such forward-looking statements, including, but not limited to: the effects of general economic conditions; the price of gold, silver and copper; misjudgements in the course of preparing forward-looking statements; risks associated with international operations; the need for additional financing; risks inherent in exploration results; conclusions of economic evaluations; changes in project parameters; currency and commodity price fluctuations; title matters; environmental liability claims; unanticipated operational risks; accidents, labour disputes and other risks of the mining industry; delays in obtaining governmental approvals or in the completion of development or construction activities; political risk; and other risks and uncertainties described in the Company’s annual financial statements for the most recently completed financial year which is available on the Company’s website at www.marianaresources.com . Although we believe that the expectations reflected in such forward-looking statements are based upon reasonable assumptions and have attempted to identify important factors that could cause actual results to differ materially from those contained in forward-looking statements, there may be other factors that cause results not to be as anticipated, estimated or intended. There can be no assurance that such statements will prove to be accurate, as actual results and future events could differ materially from those anticipated in such forward-looking statements. Accordingly, readers are cautioned not to place undue reliance on forward-looking statements. We do not undertake to update any forward-looking statements, except in accordance with applicable securities laws.

Attachments:

http://www.globenewswire.com/NewsRoom/AttachmentNg/ffff85ca-f0b5-4f25-8153-b702c86bea36

Attachments:

http://www.globenewswire.com/NewsRoom/AttachmentNg/a437e339-b2d3-4e12-a5fb-3da5e4593262

FOR FURTHER INFORMATION PLEASE CONTACT:

INDUSTRY:

Manufacturing and Production – Mining and Metals

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^Information:

Globenewswire

AP Source: Exxon seeks OK to resume Russian oil venture

April 19, 2017 by The Canadian Press

WASHINGTON — Exxon Mobil is seeking permission from the U.S. government for approval to resume drilling around the Black Sea with a Russian partner, state-owned Rosneft, according to a person familiar with the matter.

The oil giant’s request is being reviewed by the Trump administration and is certain to draw extra scrutiny because it involves a company formerly run by Secretary of State Rex Tillerson, who cultivated close ties with Russia and its president, Vladimir Putin.

The drilling venture was blocked when the U.S. imposed sanctions on Russia in 2014. Exxon applied to the Treasury Department for a waiver from the sanctions in 2015, during the Obama administration, according to the person, who spoke anonymously because the application process is confidential. Exxon has publicly disclosed licenses for other work in Russia that required waivers.

An Exxon spokesman said the company declined to comment on ongoing issues.

The Treasury Department, which would handle Exxon’s application to drill around the Black Sea, did not respond to a request for comment.

A State Department spokesman said Tillerson has recused himself from any matters involving Exxon for two years and is not involved with any decision involving the company before any government agency. Tillerson retired as Exxon CEO at the end of last year. He has known Putin for about two decades — the Russian president awarded Tillerson a special honour in 2013.

Irving, Texas-based Exxon disclosed in regulatory filings in 2015 and 2016 that it received three licenses from the Treasury Department’s Office of Foreign Assets Control to conduct “limited administrative actions” with Rosneft. The company said it was complying with all sanctions regarding investments in Russia.

The sanctions were imposed after Russia annexed the Crimea region of Ukraine in 2014. Among other things, U.S. companies were prohibited from transferring advanced technology used to drill offshore and in shale formations. Exxon was ordered to stop drilling in the Kara Sea off Russia’s northern coast. The head of Exxon’s Russian partner, Rosneft, was personally blacklisted.

As Exxon CEO, Tillerson opposed the sanctions, telling shareholders in 2014 that sanctions were usually ineffective and caused “very broad collateral damage.”

Tillerson and Exxon agreed to the venture with Rosneft in 2011. The Russia sanctions have cost the company hundreds of millions of dollars. Exxon reported in 2015 that its potential losses related to the Rosneft venture could run to $1 billion.

If the sanctions are lifted Exxon could push ahead with lucrative exploration and production opportunities in the Black Sea, Siberia and the Russian Arctic.

Exxon’s ambitions could be complicated, however, by concern over what U.S. intelligence agencies have concluded were Russian cyberattacks to interfere with the U.S. presidential election last year. Congress is also investigating possible ties between aides to then-candidate Donald Trump and Russian officials.

Exxon’s critics said that if the Trump administration approved Exxon’s request, which was reported first by The Wall Street Journal, then Congress should block it on environmental and national-interest grounds.

A Greenpeace official, Naomi Ages, said approving Exxon’s request to drill in the Black Sea would give momentum to drilling in the Arctic and “would also send a message to Russia that it can intervene in any country, including the United States, with no consequences.”

___

Koenig reported from Dallas

Martin Crutsinger And David Koenig, The Associated Press

Full production expected at Syncrude by the end of June after fire repairs

April 19, 2017 by The Canadian Press

CALGARY — Syncrude’s Mildred Lake oilsands upgrader in northern Alberta is expected to return to full operation by the end of June after production was sidelined by a fire on March 14.

Suncor Energy (TSX:SU), which owns 54 per cent of Syncrude, says in a statement that a detailed repair schedule and return-to-service plan has been adopted that will allow the facility to complete repairs as well as planned maintenance.

It says the plant, which has a maximum capacity of about 350,000 barrels per day, is operating at reduced rates, without being specific.

Suncor says fire damage was largely isolated to a piperack adjacent to the hydrotreater. One employee was hospitalized for injuries.

The company says pipeline shipments at about 50 per cent of capacity will begin in early May.

The Canadian Press

Razor Energy Corp. Announces Strategic Light Oil Asset Acquisition in the Kaybob Area of West Central Alberta and $18 Million Equity Financing

April 19, 2017 by The Canadian Press

FOR: RAZOR ENERGY CORP.
TSX VENTURE SYMBOL: RZE

Date issue: April 19, 2017
Time in: 9:55 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 19, 2017) –

NOT FOR DISTRIBUTION IN THE UNITED STATES. ANY FAILURE TO COMPLY WITH THIS
RESTRICTION MAY CONSTITUTE A VIOLATION OF U.S. SECURITIES LAW.

Razor Energy Corp. (“Razor” or the “Company”) (TSX VENTURE:RZE)
(www.razor-energy.com) is pleased to announce that it has entered into an
agreement to acquire strategic assets in west central Alberta (the “Assets”)
for cash consideration of $9.6 million, subject to customary adjustments (the
“Acquisition”). The Assets, situated within Razor’s core area, are
characterized by low decline, light oil focused production, which is primarily
operated with abundant infrastructure to complement Razor’s existing asset
portfolio. Razor is also pleased to announce that it has filed and obtained a
receipt for a preliminary short form prospectus in connection with an offering
(the “Prospectus Offering”) of subscription receipts of the Company
(“Receipts”) co-led by Haywood Securities Inc. and Jett Capital Advisors, LLC.
The Prospectus Offering is described in greater detail below.

The Acquisition will be funded with Razor’s cash reserves and through proceeds
of the Prospectus Offering.

THE ACQUISITION

The Acquisition is complementary on a geographic, geological and operational
basis and in terms of product mix with Razor’s current assets and operations in
the Swan Hills areas. On a pro forma basis, using February 2017 field estimated
production, the Company is expected to have production in excess of 3,700
boe/d, of which 85% is light oil and natural gas liquids.

The Acquisition enhances Razor’s existing asset base with similar reactivation
and re-entry opportunities, in addition to future drilling upside with proven
deliverability of light oil from the Montney formation. The primary fields
within the Assets include Kaybob South Triassic Units No. 1 and 2, Kaybob BHL
(Beaver Hill Lake) Unit No. 1 and Simonette/Karr BHL (Beaver Hill Lake) Oil
Pools.

With 95,679 (33,542 net) of acres of land, the majority of which is held by
production, Razor foresees ample drilling opportunities comprised of both
vertical and horizontal wells. Management has currently identified over 15 net
drilling locations including the potential for future horizontal targets. The
development of these properties is expected to be part of the 2018 capital
program.

The Acquisition is expected to close on or before May 24, 2017, with an
effective date of January 1, 2017.

ASSET SUMMARY

/T/

Total purchase price(1) $9.6 million
Current production (Feb 2017 field) 759 boe/d
Annual decline rate 15%
Land 95,679 (33,542 net)
acres
Net locations 15 unbooked

Forecast 2017 operating netback(2) $11.87 /boe
Reserves (Gross)
Proved developed producing (“PDP”) reserves(3) 1.5 MMboe
Total Proved (“TP”) reserves(3) 2.8 MMboe
Total proved plus probable (“P+P”) reserves(3) 3.7 MMboe
P+P RLI(4) 13 years
Reserves Value Before Tax (PV10) (3):
PDP reserve value $22.5 million
TP reserve value $36.2 million
P+P reserve value $44.7 million
Run rate cash flow(5) $3.3 million

/T/

ACQUISITION METRICS

/T/

Current production (Feb 2017 field) $12,652 per boe/d
Proved developed producing reserves(3) $6.46 per boe
Total proved reserves(3) $3.48 per boe
Total proved plus probable reserves(3) $2.62 per boe
Purchase price / PDP reserve value 43%
Purchase price / TP reserve value 27%
Purchase price / P+P reserve value 21%
Run rate cash flow(5) 2.87x

/T/

1. Subject to normal adjustments for a transaction of this nature and

adjustments related to the exercise of ROFOs and ROFRs.

2. Operating netback does not have any standard meaning prescribed by IFRS

and therefore may not be comparable with the calculation of similar
measures for other entities. Operating netback equals total petroleum
and natural gas sales less royalties and operating costs calculated on a
boe basis. Razor considers operating netback as an important measure to
evaluate its operational performance as it demonstrates its field level
profitability relative to current commodity prices. The estimated
operating netback was derived using the Corporation’s 2017 commodity
price forecast of US$54.27/Bbl WTI, $2.72/MCF AECO, and a Canadian/US
dollar exchange rate of $1.33 with the average operating netback
calculated from the Closing Date to December 31, 2017. See “Reader
Advisories – Non-IFRS Measures”.

3. Gross Company Reserves. Reserves based on the Kaybob Assets Reserves

Report effective December 31, 2016 prepared in accordance with the
requirements of the COGE Handbook as required by NI 51-101. Gross
Company Reserves means Razor’s working interest reserves assuming
completion of the Acquisition before the calculation of royalties, and
before the consideration of the Company’s royalty interests.

4. The reserve life index (“RLI”) is calculated by dividing total proved

plus probable reserves estimated at 3,683 MBoe with estimated current
production of the Kaybob Assets of 759 boe/d.

5. Run rate cash flow does not have any standard meaning prescribed by IFRS

and therefore may not be comparable with the calculation of similar
measures for other entities. Run rate cash flow is based on annualized
current production of 759 boe/d multiplied by the operating netback for
the Kaybob Assets of $11.87/boe (see Note 2 above).

/T/

2017 CAPITAL BUDGET AND REVISED GUIDANCE

Given the volatility in commodity prices and Razor’s ability to grow production
through high frequency / low capital intensive projects, Razor expects to take
a disciplined and conservative approach to the 2017 budget. The capital budget
will be reviewed continuously by management and the board of directors of the
Company (the “Board”) for changes in commodity price assumptions and project
economics. Razor remains steadfast in its conviction to maintain its financial
advantage and build a top-tier junior oil and gas company.

For fiscal 2017, the capital expenditure budget of $13.0 million, approved by
the Board prior to the Acquisition, remains unchanged. Razor continues to
invest in a combination of reactivations, re-entries, optimization activities
and waterflood management. These initiatives will be split between Swan Hills
and Kaybob areas at management’s discretion. In addition, the budget addresses
the Alberta Energy Regulator’s requirement under the Inactive Well Compliance
Program including end of life well and facility spending.

With innovative focus and disciplined capital deployment in its Swan Hills and
Kaybob areas, the Company is well positioned to execute on its growth strategy
while maintaining financial flexibility.

The Company’s 2017 revised financial and operating guidance and assumptions are
as follows:

/T/

—————————————————————————-
Average daily production 2017
—————————————————————————-

Light oil (bbls/d) 2,581
—————————————————————————-
NGLs (bbls/d) 716
—————————————————————————-
Natural gas (mcf/d) 3,319
—————————————————————————-
Oil equivalent (boe/d) 3,850
—————————————————————————-
Capital expenditures $13.0 million
—————————————————————————-
Term Loan (maturity January 31, 2021) $30.0 million
—————————————————————————-
Cash on hand, December 31, 2017 $15.1 million
—————————————————————————-
Net debt, December 31, 2017 (“Exit Net Debt”) $11.9 million
—————————————————————————-
Funds flow from operations in 2017 (“2017 FFO”)(1) $9.6 million
—————————————————————————-
Exit Net Debt to 2017 FFO(1) 1.2x
—————————————————————————-
Assumptions:
—————————————————————————-
WTI (US$/bbl) $52.50
—————————————————————————-
Exchange rate (US$/C$) 0.75
—————————————————————————-
Light sweet oil differential to WTI (C$/bbl) ($4.00)
—————————————————————————-
Average corporate oil quality discount (C$/bbl) ($3.00)
—————————————————————————-
AECO gas (C$/mcf) $2.50
—————————————————————————-

1. “Funds flow from operations” and “net debt” do not have any standardized

meaning prescribed by International Financial Reporting Standards
(“IFRS”). See “Reader Advisories – Non-IFRS Measures”.

/T/

Razor plans to continue to pursue value-driven acquisitions. Consolidation of
land and production within the Company’s existing project areas, in addition to
complementary shallow, light oil horizons within its Alberta core region, is
envisioned. Razor remains focused on adding to its inventory of high quality
projects to sustain longer-term growth.

THE EQUITY FINANCINGS

Prospectus Offering

In connection with the Acquisition, Haywood Securities Inc. and Jett Capital
Advisors, LLC, as co-lead agents and joint bookrunners, on behalf of themselves
and a syndicate of agents (collectively, the “Agents”), have agreed to offer,
on a commercially reasonable efforts agency basis, on behalf of Razor, up to
5,000,000 subscription receipts of the Company (“Subscription Receipts”) at a
price of $3.00 per Subscription Receipt for gross proceeds of up to $15,000,000
pursuant to the Prospectus Offering. Each Subscription Receipt will entitle the
holder thereof, without payment of any additional consideration and without
further action on the part of the holder, upon the Acquisition closing, to
receive one common share of the Company (a “Common Share”) and one-half of one
Common Share purchase warrant of the Company (a “Warrant”), each whole Warrant
being exercisable into one Common Share at an exercise price of $3.50 per
Common Share for a period of 12 months following the closing of the
Acquisition.

Upon closing of the Prospectus Offering, the gross proceeds from the sale of
the Subscription Receipts will be placed in escrow (the “Escrowed Proceeds”)
and released to Razor (together with any interest earned thereon) upon Haywood
Securities Inc., an behalf of the Agents, being satisfied and receiving a
certificate from the Company to the effect that: (i) there is no impediment to
completion of the Acquisition, other than the payment of the purchase price, in
all material respects in accordance with the terms of the acquisition agreement
in respect of the Acquisition, without material amendment or waiver adverse to
Razor; and (ii) receipt by the Company of all necessary regulatory and other
approvals regarding the Prospectus Offering and the Acquisition (together, the
“Escrow Release Conditions”).

If: (i) the Escrow Release Conditions are not satisfied at or before 5:00 p.m.
(Calgary time) on June 30, 2017 (the “Escrow Release Deadline”); (ii) the
Company, prior to the Escrow Release Deadline, has provided notice to Haywood
Securities Inc. or announced to the public, that it does not intend to proceed
with the Acquisition; or (iii) the acquisition agreement in respect of the
Acquisition is terminated, then the Escrowed Proceeds will be reimbursed pro
rata to each holder of the Subscription Receipts at the original subscription
price, plus such holder’s pro rata portion of the interest earned thereon, if
any (payable out of the Escrowed Proceeds).

The Agents will have an option (the “Agents’ Option”) to purchase up to an
additional 750,000 Subscription Receipts at a price of $3.00 per Subscription
Receipt to cover over-allotments, if any, exercisable in whole or in part at
any time until 30 days after the closing date. In the event the Agents’ Option
is exercised after the closing of the Acquisition, the Agents’ Option will be
exercisable for up to an additional 750,000 Common Shares and 375,000 Warrants.

The net proceeds from the Prospectus Offering will be used to fund a portion of
the purchase price of the Acquisition and to fund Razor’s capital expenditure
program.

The Subscription Receipts issued pursuant to the Prospectus Offering will be
distributed by way of a short form prospectus in Alberta, British Columbia and
Ontario and on a private placement basis in the United States pursuant to
exemptions from the registration requirements of U.S securities laws and
certain other jurisdictions as the Company and the Agents may agree on a
private placement basis. Completion of the Prospectus Offering is subject to
customary closing conditions, including the receipt of all necessary regulatory
approvals, including the approval of the TSX Venture Exchange (“TSXV”) and the
securities regulatory authorities, as applicable. Closing of the Prospectus
Offering is expected to occur on or about May 4, 2017.

Directors and officers of the Corporation are expected to participate in the
Prospectus Offering in the aggregate amount of approximately $750,000.

Private Placement

Concurrent with the Prospectus Offering, Razor is proposing to complete a
private placement of up to 923,077 Common Shares issued on a “flow-through”
basis (“CDE Flow-Through Shares”) pursuant to which subscribers will be
entitled to receive renunciation of amounts qualifying as “Canadian development
expenses” within the meaning of the Income Tax Act (Canada) (the “Tax Act”) at
a price of $3.25 per CDE Flow-Through Share for gross proceeds of up to
$3,000,000 (the “Private Placement”, and collectively with Prospectus Offering,
the “Equity Financings”). The completion of the Private Placement is subject to
customary closing conditions, including the receipt of all necessary regulatory
approvals, including the approval of the TSXV. The CDE Flow-Through Shares
issued pursuant to the Private Placement will be subject to a hold period under
applicable securities laws, expiring four months and one day following the
closing of the Private Placement. Closing of the Private Placement is expected
to occur concurrently with the closing of the Prospectus Offering.

The use of proceeds from the Private Placement will be used to incur Canadian
development expenses.

ADIVSORS

Haywood Securities Inc. acted as Financial Advisor and Jett Capital Advisors,
LLC acted as Strategic Advisor on the Equity Financings.

Canaccord Genuity Corp. acted as Financial Advisor and Eight Capital acted as
Strategic Advisor on the Acquisition.

ABOUT RAZOR

Razor Energy Corp., is a light oil focused company operating predominantly in
Alberta. Razor’s full-cycle business plan provides an opportunity to reposition
the Company as a disciplined and high-growth junior E&P company. With an
experienced management team and a strong, committed Board, growth is
anticipated to occur through timely strategic acquisitions and operations.
Razor currently trades on TSX Venture Exchange under the ticker “RZE”.

READER ADVISORIES

FORWARD-LOOKING STATEMENTS: This press release contains forward-looking
statements. More particularly, this press release contains statements
concerning, but not limited to: the anticipated annual decline rate; capital
program of the Company, including the timing of the Acquisition, payment of the
purchase price in respect of the Acquisition, expected production and cash flow
related to the Acquisition, expected number of future drilling locations
related to the Acquisition, the anticipated closing date of the Equity
Financings, the use of proceeds from the Equity Financings, reactivation
program, other capital expenditures, acquisitions, and abandonment, reclamation
and remediation expenditures; the approach to the 2017 capital budget including
reviewing the capital budget continuously; 2017 guidance including: average
daily production, cash on hand on December 31, 2017, net debt as at December
31, 2017, funds flow from operations and exit net debt to 2017 funds flow from
operations; and the Company’s acquisition strategy. In addition, the use of any
of the words “anticipate”, “believe”, “expect”, “plan”, “intend”, “estimate”,
“propose”, “project”, “can”, “will”, “should”, “continue”, “may”, and similar
expressions are intended to identify forward-looking statements. The
forward-looking statements contained herein are based on certain key
expectations and assumptions made by the Company, including but not limited to
expectations and assumptions concerning the availability of capital, current
legislation, receipt of required regulatory approval, the success of future
drilling and development activities, the performance of existing wells, the
performance of new wells, the Company’s growth strategy, general economic
conditions, availability of required equipment and services and prevailing
commodity prices.
Although the Company believes that the expectations and assumptions on which
the forward-looking statements are based are reasonable, undue reliance should
not be placed on the forward-looking statements because the Company can give no
assurance that they will prove to be correct. Since forward-looking statements
address future events and conditions, by their very nature they involve
inherent risks and uncertainties. Actual results could differ materially from
those currently anticipated due to a number of factors and risks. These
include, but are not limited to, risks associated with the oil and gas industry
in general (e.g., operational risks in development, exploration and production;
delays or changes in plans with respect to exploration or development projects
or capital expenditures; as the uncertainty of reserve estimates; the
uncertainty of estimates and projections relating to production, costs and
expenses, and health, safety and environmental risks), commodity price and
exchange rate fluctuations, changes in legislation affecting the oil and gas
industry and uncertainties resulting from potential delays or changes in plans
with respect to exploration or development projects or capital expenditures.
Please refer to the risk factors identified in the annual information form and
management discussion and analysis of the Company for the period ended December
31, 2016, on SEDAR at www.sedar.com.

The forward-looking statements contained in this press release are made as of
the date hereof and the Company undertakes no obligation to update publicly or
revise any forward-looking statements or information, whether as a result of
new information, future events or otherwise, unless so required by applicable
securities laws.

NON-IFRS MEASURES: This press release contains the terms “funds flow from
operations”, “net debt”, “operating netback” and “run rate cash flow”, which do
not have standardized meanings prescribed by IFRS and therefore may not be
comparable with the calculation of similar measures by other companies. Funds
flow from operations represents cash flow from operating activities before
changes in non-cash working capital and decommissioning expenditures.
Management uses funds flow from operations to analyze operating performance and
leverage. Net debt is calculated as long-term debt less working capital (or
plus working capital deficiency), with working capital excluding mark-to-market
risk management contracts. Management believes net debt is a useful
supplemental measure of the total amount of current and long-term debt of the
Company. Operating netback equals total petroleum and natural gas sales less
royalties and operating costs calculated on a boe basis. Razor considers
operating netback as an important measure to evaluate its operational
performance as it demonstrates its field level profitability relative to
current commodity prices. The estimated operating netback was derived using the
Corporation’s 2017 commodity price forecast of US$54.27/Bbl WTI, $2.72/MCF
AECO, and a Canadian/US dollar exchange rate of $1.33 with the average
operating netback calculated from the Closing Date to December 31, 2017. Run
rate cash flow is based on annualized current production of 759 boe/d
multiplied by the operating netback for the Kaybob Assets of $11.87/boe.

ADVISORY ON PRODUCTION INFORMATION: Unless otherwise indicated herein, all
production information presented herein has presented on a gross basis, which
is the Company’s working interest prior to deduction of royalties and without
including any royalty interests.

DRILLING LOCATIONS: This press release discloses drilling inventory as unbooked
locations. Unbooked locations are internal estimates based on our prospective
acreage and an assumption as to the number of wells that can be drilled per
section based on industry practice and internal review. Unbooked locations do
not have attributed reserves or resources. Unbooked locations have been
identified by management as an estimation of the Company’s multi-year drilling
activities based on evaluation of applicable geologic, seismic, engineering,
production and reserves information. There is no certainty that the Company
will drill all unbooked drilling locations and if drilled, there is no
certainty that such locations will result in additional oil and gas reserves,
resources or production. The drilling locations on which Razor actually drill
wells will ultimately depend upon the availability of capital, regulatory
approvals, seasonal restrictions, oil and natural gas prices, costs, actual
drilling results, additional reservoir information that is obtained and other
factors. While certain of the unbooked drilling locations have been de-risked
by drilling existing wells in relative close proximity to such unbooked
drilling locations, other unbooked drilling locations are farther away from
existing wells where management has less information about the characteristics
of the reservoir and therefore there is more uncertainty whether wells will be
drilled in such locations and if drilled there is more uncertainty that such
wells will result in additional oil and gas reserves, resources or production.

BARRELS OF OIL EQUIVALENT: The term “boe” or barrels of oil equivalent may be
misleading, particularly if used in isolation. A boe conversion ratio of six
thousand cubic feet of natural gas to one barrel of oil equivalent (6 Mcf: 1
bbl) is based on an energy equivalency conversion method primarily applicable
at the burner tip and does not represent a value equivalency at the wellhead.
Additionally, given that the value ratio based on the current price of crude
oil, as compared to natural gas, is significantly different from the energy
equivalency of 6:1; utilizing a conversion ratio of 6:1 may be misleading as an
indication of value.

This press release is not an offer of the securities for sale in the United
States. The securities offered have not been, and will not be, registered under
the U.S. Securities Act of 1933, as amended (the “U.S. Securities Act”) or any
U.S. state securities laws and may not be offered or sold in the United States
absent registration or an available exemption from the registration requirement
of the U.S. Securities Act and applicable U.S. state securities laws. This
press release shall not constitute an offer to sell or the solicitation of an
offer to buy, nor shall there be any sale of these securities, in any
jurisdiction in which such offer, solicitation or sale would be unlawful.

– END RELEASE – 19/04/2017

For further information:
Razor Energy Corp.
Doug Bailey
President and Chief Executive Officer
(403) 262-0242
www.razor-energy.com
OR
Razor Energy Corp.
Kevin Braun
Chief Financial Officer
(403) 262-0242
www.razor-energy.com

COMPANY:
FOR: RAZOR ENERGY CORP.
TSX VENTURE SYMBOL: RZE

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170419CC0106

Press Release from Marketwired 1-866-736-3779

Oilsands thirst for natural gas hits record, environmentalists decry it as ‘waste’

April 19, 2017 by The Canadian Press

CALGARY — Nearly one-third of the natural gas burned in Canada last year was used to produce crude from the oilsands, the country’s energy regulator said Wednesday, something environmentalists called a “waste” of a cleaner-burning resource.

According to a National Energy Board report, nearly 2.38 billion cubic feet per day or a record 29 per cent of purchased natural gas was used for oilsands production in Alberta in 2016. That’s up from the 730 million cf/d or 12 per cent of total demand in 2005.

Natural gas is used in the oilsands to generate steam to inject into underground formations to thin the heavy, sticky bitumen crude and allow it to be pumped to the surface.

The growth in so-called “thermal” projects is the main driver behind increased oilsands demand for natural gas, the NEB said.

Environmentalists said that natural gas could be better used to heat houses, generate electricity or make plastics.

“Rather than wasting this relatively low-carbon fuel to extract high-carbon oil from tarsands, let’s use it to heat homes as we speed the transition to the 100 per cent renewable future that science demands,” said Greenpeace campaigner Mike Hudema in an email.

Andrew Read, a senior analyst with the Pembina Institute, said the report highlights the need for a national energy plan that aligns use of energy with Canada’s climate targets.

“This is basically using our cleaner fossil fuel resources to produce dirtier transportation fuels,” Read said.

The NEB report said spot prices in Alberta for natural gas plunged to a record low 58 cents per gigajoule (about 55 cents per thousand cubic feet) on May 8 last year, when wildfires near Fort McMurray forced the shutdown of gas supply pipelines to oilsands projects.

But commodity analyst Martin King of GMP FirstEnergy in Calgary said the oilsands are not a significant influence on long-term gas pricing.

“Overall, gas demand outside of Alberta power generation and the oilsands isn’t really moving anyway,” he said.

He said Canadian prices for natural gas are influenced mainly by weather-related demand and production trends in the United States, Canada’s largest export market. He said the average spot price last year in Alberta of $2.17 per thousand cubic feet was the lowest since 1998.

Canada’s demand for natural gas is only about half of its production, now at more than 15 billion cf/d, and that output can be quickly ramped up if new demand arrives in the form of West Coast liquefied natural gas export facilities, King said.

The NEB said natural gas is also used in oilsands mining to heat water to separate bitumen from sand. Miners that upgrade bitumen into synthetic crude oil also use gas to produce hydrogen needed for that process.

Follow @HealingSlowly on Twitter.

Dan Healing, The Canadian Press

Northwest Pipe Company Announces First Quarter 2017 Earnings Conference Call

April 19, 2017 by The Canadian Press

FOR: NORTHWEST PIPE COMPANY

VANCOUVER, Wash., April 19, 2017 (GLOBE NEWSWIRE) — Northwest Pipe Company (Nasdaq:NWPX) today announced it intends to release first quarter 2017 results after market close on Tuesday, May 2, 2017. A teleconference to discuss the financial results is scheduled to begin at 7:00 am PDT on Wednesday, May 3, 2017. Northwest Pipe officials participating on the call will be Scott Montross, President and Chief Executive Officer, and Robin Gantt, Chief Financial Officer. To listen to the live call, visit the Northwest Pipe Company website, www.nwpipe.com, under Investor Relations. For those unable to listen to the live call, a replay will be available approximately one hour after the event and will remain available until Wednesday, May 31, 2017 by dialing 1-800-778-9712 passcode 6301. About Northwest Pipe CompanyNorthwest Pipe Company is the largest manufacturer of engineered steel pipe water systems in North America. The Company’s Water Transmission manufacturing facilities are strategically positioned to meet North America’s growing needs for water and wastewater infrastructure. The Company serves a wide range of markets and their solution-based products are a good fit for applications including: water transmission, plant piping, tunnels, and river crossings. The Company is headquartered in Vancouver, Washington and has manufacturing facilities across the United States and one manufacturing facility in Mexico.For more information, visit www.nwpipe.com.

FOR FURTHER INFORMATION PLEASE CONTACT:

Contact: Robin Gantt Chief Financial Officer (360) 397-6325

INDUSTRY:

Aerospace and Defense – Electronics and Communications

SUBJECT: CAL

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Contact: Robin Gantt Chief Financial Officer (360) 397-6325}

Globenewswire

Novelion Therapeutics’ Request to Voluntarily Delist from the Toronto Stock Exchange Granted

April 19, 2017 by The Canadian Press

FOR: NOVELION THERAPEUTICS, INC.

VANCOUVER, British Columbia, April 19, 2017 (GLOBE NEWSWIRE) — Novelion Therapeutics, Inc. (NASDAQ:NVLN) (TSX:NVLN), a biopharmaceutical company dedicated to developing new standards of care for individuals living with rare diseases, today announced that, as part of its cost rationalization process, the Company’s request to voluntarily delist its common shares on the Toronto Stock Exchange (“TSX”) at the close of markets on May 3, 2017 has been granted. The Company’s shares will continue to trade on the NASDAQ Global Select Market under the symbol “NVLN”.

The Company believes that the low trading volume of its shares on the TSX over a sustained period no longer justifies the financial and administrative costs associated with maintaining a dual listing. Canadian shareholders will be able to continue to trade the Company’s shares on the NASDAQ exchange through their brokers who have U.S. registered broker-dealer affiliates.

About Novelion Therapeutics Novelion Therapeutics is a biopharmaceutical company dedicated to developing new standards of care for individuals living with rare diseases. Novelion has a diversified commercial portfolio through its indirect subsidiary, Aegerion Pharmaceuticals, Inc., which includes MYALEPT® and JUXTAPID®, and is also developing zuretinol acetate for the treatment of inherited retinal disease caused by underlying mutations in RPE65 or LRAT genes. The company seeks to advance its portfolio of rare disease therapies by investing in science and clinical development.

FOR FURTHER INFORMATION PLEASE CONTACT:

CONTACT: Amanda Murphy, Director, Investor Relations & Corporate Communications Novelion Therapeutics 857-242-5024 Amanda.murphy@novelion.com

INDUSTRY:

Pharmaceuticals and Biotech – Biotech

SUBJECT: STK

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: CONTACT: Amanda Murphy, Director, Investor Relations & Corporate Communications Novelion Therapeutics 857-242-5024 Amanda.murphy@novelion.com}

Globenewswire

NOVADAQ to Report First Quarter 2017 Financial results on May 3, 2017

April 19, 2017 by The Canadian Press

FOR: NOVADAQ TECHNOLOGIES INC.

TORONTO, April 19, 2017 (GLOBE NEWSWIRE) — NOVADAQ Technologies Inc. (NASDAQ:NVDQ) (TSX:NDQ), the leading provider of proven comprehensive fluorescence imaging solutions that improve clinical outcomes and reduce healthcare costs in minimally invasive and open surgeries, today announced that it will release financial results for the first quarter of 2017 after the close of trading on Wednesday, May 3, 2017. The Company’s management team will host a corresponding conference call beginning at 4:30 p.m. ET.

Investors interested in listening to the conference call may do so by dialing 877-407-8031 (within Canada and the U.S.) or 201-689-8031 (outside Canada and the U.S.). A live and archived webcast of the event will be available on the “Investor Relations” section of the Company’s website at: www.novadaq.com.

A replay of the call will be available for 48 hours by calling (877) 481-4010 (within Canada and the U.S.) or (919) 882-2331 (outside Canada and the U.S.), using Conference ID:10307.

About NOVADAQ Technologies Inc. NOVADAQ’s global mission is to enable physicians with point-of-care imaging solutions that provide real-time clinically significant and actionable information to improve care quality and lower healthcare costs. Using NOVADAQ’s SPY fluorescence imaging technology, physicians can personalize therapy and achieve optimal results through the precise visualization of blood flow in vessels, micro-vessels, tissue perfusion and critical anatomical structures during the course of treatment. SPY technology enables the delivery of personalized therapies and the achievement of the optimal results for each individual patient. More than 240 peer-reviewed publications demonstrate that the use of SPY technology will reduce post-procedure complication rates and the cost of care for a broad variety of surgical treatments for cancer, cardiovascular diseases and other conditions, helping to ensure that patients benefit from the very best possible treatment and outcome.

SPY Imaging Systems are U.S. Food and Drug Administration 510(k) cleared, Health Canada licensed, CE Marked and registered worldwide for use in multiple surgical specialties and medical applications. The endoscopic version of SPY technology, known as PINPOINT, combines the fluorescence imaging capabilities of SPY with the high definition visible light visualization to establish a new standard in the quality and performance of minimally invasive surgery. NOVADAQ’s LUNA System is used to visualize blood flow and tissue perfusion while treating patients with atherosclerotic cardiovascular disease that impairs blood flow to the extremities and increases the risk for the development of complications such as acute and chronic non-healing wounds and limb loss. NOVADAQ is the exclusive worldwide distributor of LifeNet Health’s DermACELL acellular tissue products for wound and breast reconstruction surgery.

FOR FURTHER INFORMATION PLEASE CONTACT:

For more information, please contact: Lynn Pieper Lewis or Leigh Salvo (415) 937-5404 investors@novadaq.com

INDUSTRY:

Medical and Healthcare – Medical Devices

SUBJECT: MIS

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: For more information, please contact: Lynn Pieper Lewis or Leigh Salvo (415) 937-5404 investors@novadaq.com}

Globenewswire

High Response and Remission Rates in Anti-TNFa Naïve Patients Treated with Qu Biologics’ Novel Immune Therapy for Crohn’s Diseas

April 19, 2017 by The Canadian Press

FOR: QU BIOLOGICS

VANCOUVER, British Columbia, April 19, 2017 (GLOBE NEWSWIRE) — Qu Biologics Inc., a biopharmaceutical company developing Site Specific Immunomodulators (SSIs), a unique platform of immunotherapies designed to restore the body’s innate immune system, reports high response and remission rates in anti-TNFa naïve patients in its recently completed randomized, placebo controlled trial in moderate to severe Crohn’s disease (CD). In the study, treatment with QBECO SSI for 8 weeks resulted in a statistically significant response rate of 64% compared to 27% in the placebo control (p=0.041). Clinical remission rates after 8 weeks of treatment were also impressive at 50%, more than double the placebo rate of 23% (p=0.16). Clinical response and remission rates were assessed using the standard Crohn’s Disease Activity Index (CDAI), defined as a decrease in CDAI of =70 points (response) and CDAI score =150 points (remission).

Dr. Brian Bressler, UBC Clinical Assistant Professor of Medicine, Division of Gastroenterology, and Principal Investigator of the trial, explained, “Remission rates in similarly designed randomized placebo controlled trials with current ‘gold-standard’ treatments for CD, Remicade® and Humira®, are approximately 35% in anti-TNFa naïve patients at similar time-points, so the 50% remission rate in this important patient group in this trial is promising.” Dr. Hal Gunn, CEO of Qu Biologics, added, “We are pleased with the high response and remission rates in the QBECO-treated anti-TNFa naïve CD patients at the early Week 8 time-point, particularly as data from the trial suggests that many patients continue to improve on SSI treatment after this time-point. Future studies will assess response and remission rates with longer treatment periods.”

Anti-TNFa naïve patients (i.e., patients who have not been treated with the immunosuppressive drugs Remicade®, Humira®, Cimzia® and Simponi®) represent approximately two-thirds of Crohn’s disease patients in Europe and North America and a higher percentage of patients elsewhere. Patients who have previously been treated with and failed anti-TNFa agents are known to be a more difficult to treat patient group. Data from the trial’s cytokine analysis suggests that patients previously treated with anti-TNFa agents may have greater baseline innate immune suppression/dysregulation. SSI treatment is designed to restore innate immune function and therefore, a longer period of SSI treatment may be required in this latter patient group. As Jim Pankovich, Qu Biologics’ VP Clinical Operations and Drug Development noted, “In patients previously treated with TNFa inhibitors who completed 16 weeks of SSI treatment, 40% were in remission, suggesting that this more challenging patient group may respond to QBECO SSI with longer treatment.”

Dr. Hal Gunn added, “When this data is combined with the genetic and cytokine biomarker data from the trial, it suggests that we may be able to select patient groups with an even higher probability of response and remission with QBECO SSI treatment. These results are very encouraging and will guide us in the design of our next study and in future Phase 3 studies.” Qu Biologics plans to initiate a larger follow-on clinical trial in Crohn’s disease in late 2017/early 2018 with a 52-week QBECO SSI treatment period.

For more information about Qu Biologics and the science behind SSIs, please visit www.qubiologics.com.

About Qu Biologics Qu Biologics is a Vancouver-based private clinical stage biopharmaceutical company developing Site Specific Immunomodulators (SSI), a novel class of immunotherapies. SSIs are designed to stimulate an innate immune response in targeted organs or tissues to reverse the chronic inflammation underlying many conditions including cancer, inflammatory bowel disease, inflammatory lung disease and arthritis. SSIs are a broad platform technology being tested in multiple disease indications, including Health Canada approved clinical trials in lung cancer, Crohn’s disease and Ulcerative Colitis.

Backed by a prestigious group of scientific advisors and board members, Qu Biologics is led by a management team that includes co-founder and CEO Dr. Hal Gunn, a physician and expert on the body’s immune response to chronic disease; and Chief Medical Officer Dr. Simon Sutcliffe, former CEO of the BC Cancer Agency and a distinguished clinician, scientist and leader in cancer control in Canada and internationally.

Qu Biologics Inc. cautions you that statements included in this press release that are not a description of historical facts may be forward-looking statements. Forward-looking statements are only predictions based upon current expectations and involve known and unknown risks and uncertainties. You are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date of release of the relevant information, unless explicitly stated otherwise. Actual results, performance or achievement could differ materially from those expressed in, or implied by, Qu Biologics’ forward-looking statements due to the risks and uncertainties inherent in Qu Biologics’ business including, without limitation, statements about: the progress and timing of its clinical trials; difficulties or delays in development, testing, obtaining regulatory approval, producing and marketing its products; unexpected adverse side effects or inadequate therapeutic efficacy of its products that could delay or prevent product development or commercialization; the scope and validity of patent protection for its products; competition from other pharmaceutical or biotechnology companies; and its ability to obtain additional financing to support its operations. Qu Biologics does not assume any obligation to update any forward-looking statements except as required by law.

FOR FURTHER INFORMATION PLEASE CONTACT:

For more information regarding this press release, contact: Hal Gunn, MD CEO Qu Biologics Inc. Phone: 604.734.1450 Email: media@qubiologics.com

INDUSTRY:

Pharmaceuticals and Biotech – Biotech

SUBJECT: PDT

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: For more information regarding this press release, contact: Hal Gunn, MD CEO Qu Biologics Inc. Phone: 604.734.1450 Email: media@qubiologics.com}

Globenewswire

Total Energy Services Inc. Announces 2017 First Quarter Conference Call and Webcast

April 19, 2017 by The Canadian Press

FOR: TOTAL ENERGY SERVICES INC.TSX SYMBOL: TOTDate issue: April 19, 2017Time in: 7:21 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 19, 2017) – Total Energy Services Inc.
(“Total”) (TSX:TOT) will conduct a conference call and webcast following …

ZeptoLab’s C.A.T.S.: Crash Arena Turbo Stars – Now Available on iOS and Android

April 19, 2017 by The Canadian Press

FOR: ZEPTOLAB

LONDON , April 19, 2017 (GLOBE NEWSWIRE) — Pump up your tires and prepare for battle! C.A.T.S.: Crash Arena Turbo Stars, the latest mobile PvP game from Cut the Rope and King of Thieves creators, is now available for free on iOS and Android. Build and customize battle cars in the role of a street kitten, and go head-to-head against other players to become the Crash Arena champion.

Get C.A.T.S.: Crash Arena Turbo Stars for free:

Apple App Store: https://itunes.apple.com/us/app/cats-crash-arena-turbo-stars/id1208561922
Google Play: https://play.google.com/store/apps/details?id=com.zeptolab.cats.google

View the official launch trailer here: https://youtu.be/Ssb-MHsOVvM

Your road to the top of the World Championship starts in the garage. Experiment, upgrade, and combine a variety of deadly hand-made weapons and gadgets — from drills and chainsaws to soda pop bottles — to build a machine that’s unlike any other. When your car is good enough, enter the Championship and fight against real players from all over the world in uncontrollable physics-based battles. Defeat all opponents in the group to move into the next stage. Higher stages allow access to higher ranked weaponry and accessories.

“We made sure that battles in C.A.T.S. are unpredictable, frantic and exciting to watch,” says ZeptoLab’s Co-founder Efim Voinov. “We are looking forward to all the amazing battles our players will experience — and share.”

And that’s not all! Customize your ride with different stickers, fight against friends to see who’s the better engineer, and bet the spare parts on the strongest machine created by other players to get bonuses for your weapons.

Get the game now for free and become the star of the Arena!

Apple App Store: https://itunes.apple.com/us/app/cats-crash-arena-turbo-stars/id1208561922
Google Play: https://play.google.com/store/apps/details?id=com.zeptolab.cats.google

Art assets are available in the press kit: https://drive.google.com/drive/u/0/folders/0B3ZKpPwCJsy0NzY5dEV6YS04WE0

For more information:

Visit the official website: www.catsthegame.com
Like the game on Facebook: www.facebook.com/catsthegame
Follow the game on Twitter: www.twitter.com/catsthegame
Subscribe to the official YouTube channel: https://www.youtube.com/c/CATSCrashArenaTurboStars

About ZeptoLabZeptoLab UK Limited is a global gaming and entertainment company best known for developing the award-winning hit franchise Cut the Rope®. Cut the Rope games have been downloaded more than 1 billion times by users around the world since the first game’s debut in October 2010. The company has also released King of Thieves, a massive multiplayer mobile title with more than 50 million downloads so far, as well as Pudding Monsters and My Om Nom games. All of the games can be enjoyed on all major mobile platforms, including (but not limited to): iOS, Google Play, Amazon and Windows Phone. For more information, please visit www.zeptolab.com.

FOR FURTHER INFORMATION PLEASE CONTACT:

Media Contact TriplePoint for ZeptoLab in US zeptolab@triplepointpr.com (415) 955-8500 ZeptoLab UK Ltd. Staple Court, 11 Staple Inn Buildings London, WC1V 7QH United Kingdom info@zeptolab.com +44 7949 320701

INDUSTRY:

Computers and Software – Software

SUBJECT: PDT

NEWS RELEASE TRANSMITTED BY Globe Newswire

^{Information: Media Contact TriplePoint for ZeptoLab in US zeptolab@triplepointpr.com (415) 955-8500 ZeptoLab UK Ltd. Staple Court, 11 Staple Inn Buildings London, WC1V 7QH United Kingdom info@zeptolab.com +44 7949 320701}

Globenewswire

Suncor Energy provides update on Syncrude return to service plan

April 19, 2017 by The Canadian Press

FOR: SUNCOR ENERGY INC.TSX SYMBOL: SUNYSE SYMBOL: SUDate issue: April 19, 2017Time in: 6:00 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 19, 2017) – Suncor today provided an
update on the Syncrude Mildred Lake Oil Sands facility following the …

Mullen Group Ltd. Reports First Quarter Financial Results and Increased 2017 Capital Budget

April 19, 2017 by The Canadian Press

FOR: MULLEN GROUP LTD.TSX SYMBOL: MTLDate issue: April 19, 2017Time in: 5:45 PM eAttention:
OKOTOKS, ALBERTA–(Marketwired – April 19, 2017) – Mullen Group Ltd. (TSX:MTL)
(“Mullen Group”, “We”, “Our” and/or the “Corporation”), one of Canada’s largest
s…

Voting Results of Africa Oil Annual General Meeting

April 19, 2017 by The Canadian Press

FOR: AFRICA OIL CORP.TSX SYMBOL: AOIOMX SYMBOL: AOIDate issue: April 19, 2017Time in: 5:30 PM eAttention:
VANCOUVER, BRITISH COLUMBIA–(Marketwired – April 19, 2017) – Africa Oil Corp.
(TSX:AOI) (OMX:AOI) (“Africa Oil”, “AOC” or the “Company”) announce…

Bonterra Energy Corp. Announces Completion of the Annual Banking Review

April 19, 2017 by The Canadian Press

FOR: BONTERRA ENERGY CORP.TSX SYMBOL: BNEDate issue: April 19, 2017Time in: 5:30 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 19, 2017) – Bonterra Energy Corp.
(www.bonterraenergy.com) (TSX:BNE) (“Bonterra” or “the Company”) today
announces th…

United Hunter Oil and Gas Corp. Announces a Non-Brokered Private Placement

April 19, 2017 by The Canadian Press

FOR: UNITED HUNTER OIL & GAS CORP.
TSX VENTURE SYMBOL: UHO
FRANKFURT SYMBOL: A118VK

Date issue: April 19, 2017
Time in: 5:00 PM e

Attention:

VANCOUVER, BRITISH COLUMBIA–(Marketwired – April 19, 2017) – United Hunter Oil
and Gas Corp. (TSX VENTURE:UHO)(FRANKFURT:A118VK) (“UHO” or the “Corporation”)
announces a non-brokered private placement (the “Private Placement”) of up to
1,000,000 Common Shares at a price of $0.20 per Common Share, with a 1/2
warrant per share issued for gross proceeds of up to $1 million.

Private Placement

The Private of up to 1,000,000 Common Shares at a price of $0.20 per Common
Share, with a 1/2 warrant per share issued, for gross proceeds of up to
$1,000,000 will be non-brokered, however, the Company may pay finder’s fees in
accordance with the rules and policies of the TSXV. It is expected that the
Common Shares offered under the Private Placement will be eligible under all
usual statutes including RRSPs and TFSAs.

The Private Placement is subject to certain customary conditions, including,
but not limited to, the execution of definitive subscription agreements with
subscribers, and the receipt of any and all necessary regulatory approvals,
including that of the TSXV. Closing of the Private Placement is anticipated to
occur within thirty days or as long as the Corporation deems necessary. All
securities issued in connection with the Private Placement will be subject to a
statutory hold period of four months plus one day from the date of completion
of the Private Placement in accordance with applicable securities legislation.

The net proceeds from the Private Placement will be used for continuing
expenses associated with the ongoing due diligence and legal expenses
associated with the Company’s interest in several oil and gas projects, general
working capital and repayment of debt.

About the Issuer

United Hunter Oil & Gas Corp. (www.unitedhunteroil.com) is a Canadian based
corporation with management very experienced in the oil and gas industry with
projects in the United States. United Hunter Oil & Gas Corp. is publicly traded
on the TSX Venture Exchange (TSX VENTURE:UHO) and Frankfurt Exchange
(FRANKFURT:A118VK). The Corporation’s public filings may be found at
http://www.sedar.com.

Certain statements contained in this press release constitute “forward-looking
statements” as such term is used in applicable Canadian and US securities laws.
These statements relate to analyses and other information that are based upon
forecasts of future results, estimates of amounts not yet determinable and
assumptions of management.

Forward-looking statements are made based on management’s beliefs, estimates
and opinions on the date the statements are made and the Corporation undertakes
no obligation to update forward-looking statements and if these beliefs,
estimates and opinions or other circumstances should change, except as required
by applicable law.

– END RELEASE – 19/04/2017

For further information:
Timothy Turner
CEO
(713) 858-3329
info@unitedhunteroil.com

COMPANY:
FOR: UNITED HUNTER OIL & GAS CORP.
TSX VENTURE SYMBOL: UHO
FRANKFURT SYMBOL: A118VK

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170419CC0085

Press Release from Marketwired 1-866-736-3779

United Hunter Oil and Gas Corp. Announces Two New Corporate Appointments

April 19, 2017 by The Canadian Press

FOR: UNITED HUNTER OIL & GAS CORP.
TSX VENTURE SYMBOL: UHO
FRANKFURT SYMBOL: A118VK

Date issue: April 19, 2017
Time in: 5:00 PM e

Attention:

VANCOUVER, BRITISH COLUMBIA–(Marketwired – April 19, 2017) – United Hunter Oil
& Gas Corp. (“Corporation”) (TSX VENTURE:UHO)(FRANKFURT:A118VK) announces the
appointment of Miles Nagamatsu as Chief Financial Officer of the Corporation,
effective immediately. Mr. Nagamatsu previously served the Corporation in a
similar capacity and we welcome his services once again. A Chartered
Professional Accountant, Chartered Accountant with over 35 years of experience
who serves as Chief Financial Officer and director of public and private
companies primarily in the mineral exploration and investment management
sectors. Mr. Nagamatsu has over 35 years of experience in accounting,
management, lending, restructurings and turnarounds.

Since 1993, Miles has acted as a Chief Financial Officer of public and private
companies primarily in the mineral exploration and investment management
sectors. For over 25 years, Mr. Nagamatsu has served as volunteer Chair of the
Finance Committee and Director of Cystic Fibrosis Canada. He holds a Bachelor
of Commerce degree from McMaster University and is a Chartered Accountant.

Furthermore, the Corporation would like to announce the appointment of Mr. Alec
Robinson, as a new member to the Board of Directors. Alec brings an extensive
level of experience encompassing the many senior level executive positions that
he held within a major oil company and the work efforts he held with several
junior exploration companies. His experience includes several international,
onshore and offshore, exploration and production projects, which span from
South America to Europe, the Middle East and Africa. He has a Master’s Degree
in petroleum geology from Imperial College, London.

Timothy Turner, CEO of the Corporation, stated that “United Hunter is pleased
to welcome both Miles Nagamatsu, as the new Chief Financial Officer, and Alec
Robinson, as a new Board Member, to the Corporation. I have had the opportunity
to work with Miles in the past and I know that he will bring a high level of
energy and work ethic to this position and to our organization. Also, we are
pleased to welcome Mr. Alec Robinson to the Board of Directors. We anticipate
that Alec’s worldwide exploration and production experience will deliver an
additional level of experience so as to continue our efforts to locate scalable
projects for the Corporation and look forward to his contribution to the
Corporation’s future successes. He will be a significant asset to our Board and
we look forward to working with both gentlemen well into the future.”

Both appointments will require filing the necessary regulatory paperwork to the
TSX Venture exchange.

Certain statements in the documents referred to in this press release may
constitute forward-looking statements within the meaning of applicable
securities laws. Forward-looking statements include, but are not limited to,
statements concerning (i) the acquisition of the Property Interest; and (ii)
potential results from the Property Interest. Forward-looking statements
generally can be identified by the use of forward looking terminology such as
“outlook”, “objective”, “may”, “will”, “expect”, “intend”, “estimate”,
“anticipate”, “believe”, “should”, “plans” or “continue”, or similar
expressions suggesting future outcomes or events. Such forward-looking
statements reflect management’s current beliefs and are based on information
currently available to management. Forward-looking statements involve risks and
uncertainties that could cause actual results to differ materially from those
contemplated by such statements. Such forward-looking statements are subject to
risks and uncertainties that may cause actual results, performance or
developments to differ materially from those contained in the statements
including, without limitation, the risks that: (1) UHO may not achieve the
results currently anticipated; and (2) UHO may not be able to obtain financing
in the future. Although UHO believes that the expectations reflected in its
forward-looking information are reasonable, undue reliance should not be placed
on forward-looking information because UHO can give no assurance that such
expectations will prove to be correct. In addition to other factors and
assumptions which may be identified in this press release, assumptions have
been made regarding and are implicit in, among other things, the timely receipt
of required regulatory approvals. Details of the risk factors relating to UHO
and its business are discussed under the heading “Risk Factors” in the
Management Discussion & Analysis dated November 22, 2016, a copy of which is
available on UHO’s SEDAR profile at www.sedar.com. Readers are cautioned that
the foregoing list is not exhaustive of all factors and assumptions which have
been used. Forward-looking information is based on current expectations,
estimates and projections that involve a number of risks and uncertainties
which could cause actual results to differ materially from those anticipated by
UHO and described in the forward looking information. The forward-looking
information contained in this press release is made as of the date hereof and
UHO undertakes no obligation to update publicly or revise any forward-looking
information, whether as a result of new information, future events or
otherwise, unless required by applicable securities laws. The forward looking
information contained in this press release is expressly qualified by this
cautionary statement.

Neither the TSX Venture Exchange nor its regulation services provider (as that
term is defined in the policies of the TSX Venture Exchange) accepts
responsibility for the adequacy or accuracy of this release.

– END RELEASE – 19/04/2017

For further information:
Timothy Turner
CEO
(832) 487-0813
info@unitedhunteroil.com
OR
Mr. Miles Nagamatsu
CFO
miles.nagamatsu@gmail.com

COMPANY:
FOR: UNITED HUNTER OIL & GAS CORP.
TSX VENTURE SYMBOL: UHO
FRANKFURT SYMBOL: A118VK

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170419CC0086

Press Release from Marketwired 1-866-736-3779

Harvest Operations Files 2016 Annual Report on Form 20-F

April 19, 2017 by The Canadian Press

FOR: HARVEST OPERATIONS CORP.

Date issue: April 19, 2017
Time in: 4:30 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 19, 2017) – Harvest Operations Corp.
(“Harvest” or the “Company”) announced that the Company has filed its 2016 Form
20-F with the United States Securities and Exchange Commission (“SEC”) for the
year ended December 31, 2016.

The Company filed its Audited Consolidated Financial Statements and related
Management’s Discussion and Analysis (“MD&A”) on SEDAR, EDGAR and SGXNet on
February 23, 2017 and filed its Annual Information Form (“AIF”) and its
Statement of Reserves Data and Other Oil and Gas Information Form 51-101F1 on
March 28, 2017 for the year ended December 31, 2016.

An electronic copy of each document is available on Harvest’s website at
www.harvestenergy.ca and on Harvest’s System for Electronic Document Analysis
and Retrieval (“SEDAR”) profile at www.sedar.com.

HARVEST CORPORATE PROFILE

Harvest is a wholly-owned, subsidiary of Korea National Oil Corporation
(“KNOC”). Harvest is a significant operator in Canada’s energy industry
offering stakeholders exposure to exploration, development and production of
crude oil and natural gas (Upstream) and an oil sands project under
construction and development in northern Alberta (BlackGold).

KNOC is a state owned oil and gas company engaged in the exploration and
production of oil and gas along with storing petroleum resources. KNOC will
fully establish itself as a global government-run petroleum company by applying
ethical, sustainable and environment-friendly management and by taking
corporate social responsibility seriously at all times. For more information on
KNOC, please visit their website at www.knoc.co.kr/ENG/main.jsp.

ADVISORY

Certain information in this press release constitute “forward-looking
statements” which involve known and unknown risks, uncertainties and other
factor that may cause actual results to be materially different from future
results, performance or achievements expressed or implied by such statements.
Words such as “expects”, “anticipates”, “projects”, “intends”, “plans”, “will”,
“believes”, “seeks”, “estimates”, “should”, “may”, “could”, and variations of
such words and similar expressions are intended to identify such
forward-looking statements.

Readers are cautioned that the forward-looking information may not be
appropriate for other purposes and the actual results may differ materially
from those anticipated. Although management believes that the forward-looking
information is reasonable based on information available on the date such
forward-looking statements were made, no assurances can be given as to future
results, levels of activity and achievements. Therefore, readers are cautioned
not to place undue reliance on forward-looking statements as there can be no
assurance that the plans, intentions or expectations upon which they are based
will occur. Although we consider such information reasonable at the time of
preparation, it may prove to be incorrect and actual results may differ
materially from those anticipated. Harvest assumes no obligation to update
forward-looking statements should circumstances, estimates or opinions change,
except as required by law. Forward-looking statements contained in this press
release are expressly qualified by this cautionary statement.

– END RELEASE – 19/04/2017

For further information:
INVESTOR & MEDIA CONTACT:
Greg Foofat, Investor Relations
Harvest Operations Corp.
Toll Free Investor Mailbox: (866) 666-1178
information@harvestenergy.ca
www.harvestenergy.ca

COMPANY:
FOR: HARVEST OPERATIONS CORP.

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170419CC0081

Press Release from Marketwired 1-866-736-3779

Don’t Let Your Company Go Up In Smoke – What Oilpatch Employers Need To Understand Regarding the Looming Legalization Of Marijuana – Wendy Ferguson – BHRLR, CPHR

June 28, 2017April 19, 2017 by EnergyNow Media

By Wendy Ferguson – BHRLR, CPHR – Ferguson HR Consulting Many of the news articles you have been reading over the past few weeks and months pertain to the impending legalization of marijuana in Canada. It is definitely the latest buzz, especially in the energy sector. Most of us know … Read more

Canada is Becoming Increasingly Polarized On Policy Alignment With the U.S. – David Yager

June 30, 2017April 19, 2017 by EnergyNow Media

David Yager – Yager Management Ltd. Oilfield Service Management Consulting – Oil & Gas Writer – Energy Policy Analyst April 19, 2017 Exactly how Canada is going to manage its basket of major domestic and international policy issues with Donald Trump in the White House remains unknown. One problem is … Read more

Brookfield-led group to buy all 213 Loblaw gas stations for $540 million

April 19, 2017 by The Canadian Press

TORONTO — Loblaw is selling all 213 of its gas stations across the country for $540 million to Brookfield Business Partners and its partners.

While Brookfield (TSX:BBU.UN) would rebrand the stations to Mobil, they would continue to use the PC Plus loyalty program offered by Loblaw (TSX:L).

The proposed deal is subject to certain conditions, but is expected to close in this year’s third quarter.

Brookfield Business Partners, a unit of Brookfield Asset Management (TSX:BAM.A), says it sees potential for expanding the network of Loblaw-owned gas stations and associated kiosks after the deal closes.

“This transaction aligns with our strategy of owning and adding value to high quality businesses with solid long-term fundamentals in sectors we know well,” Cyrus Madon, CEO of Brookfield Business Partners, said in a statement Wednesday.

“We look forward to working with Loblaw to enhance and grow the current network of gas stations.”

Brookfield said it would use the Mobil fuel brand under an agreement with Calgary-based Imperial Oil Ltd. (TSX:IMO), a subsidiary of Houston-based ExxonMobil, one of the biggest integrated oil and gas companies in the United States.

Loblaw, Canada’s largest operator of grocery and pharmacy stores, is the latest company to divest its gas stations, which have been largely purchased by companies that focus on fuel distribution or convenience stores.

Last year, Imperial Oil sold its remaining 497 Esso retail stations in Canada to five buyers for a total of $2.8 billion.

Among the buyers was Parkland Fuel Corp. of Red Deer, Alta., which acquired Imperial Oil’s On the Run/Marche Express convenience store franchise system and 17 Esso stations.

On Tuesday, Parkland (TSX:PKI) announced a $1.5 billion deal to buy Chevron Canada’s downstream fuel business, including 129 retail gas stations in the Vancouver area and the Chevron refinery in Burnaby, B.C.

Loblaw said it expects to use proceeds from the sale of its fuel business for its corporate activities.

“This is a positive outcome for our customers, our gas station operators, and our company,” said Sarah Davis, the president of Loblaw Companies Ltd., in a news release.

The Canadian Press

Midwest Energy Emissions Corp. Announces Preliminary Q1 2017 Revenues; Reiterates 2017 Revenue Guidance

April 19, 2017 by The Canadian Press

SPOT Satellite Devices Reach Major Milestone with 5,000 Rescues Worldwide

April 19, 2017 by The Canadian Press

FOR: GLOBALSTAR CANADA SATELLITE CO.
NYSE SYMBOL: GSAT

Date issue: April 19, 2017
Time in: 8:30 AM e

Attention:

30% of all SPOT rescues worldwide have been initiated in Canada

MISSISSAUGA, ONTARIO–(Marketwired – April 19, 2017) –

Note to editors: There is an infographic associated with this press release.

Globalstar Canada Satellite Co., a wholly owned subsidiary of Globalstar Inc.
(NYSE:GSAT) and a leader in satellite messaging and emergency notification
technologies, announced today that its SPOT family of products has surpassed
the milestone of initiating 5,000 rescues since its launch in 2007. These
rescues have taken place on six continents and in over 89 countries. 30% of
SPOT rescues around the world have been initiated in Canada (1,500 rescues and
counting).

SPOT provides affordable location-based messaging and a lifesaving S.O.S.
service to hundreds of thousands of users worldwide including campers, hikers,
fishermen, snowmobilers, hunters, motorcyclists and those who enjoy outdoor
adventures and travelling off-the-grid. SPOT users have the ability to track
assets, use location-based messaging and get help when beyond cellular
coverage.

1,500+ SPOT rescues initiated in Canada

In Canada, SPOT has been used to initiate more than 1,500 rescues since 2007.
The majority of these rescues have taken place in British Columbia (41%),
followed by Alberta (17%), the North including Yukon, Northwest Territories and
Nunavut (17%), Quebec (13%) and Ontario (12%). SPOT rescue incidents in Canada
primarily involve hiking and mountain sports, boating and water sports, motor
vehicle and medical incidents. In 2016, the SPOT family of products set a new
safety record in Canada with 274 rescues.

There are more than 65,000 SPOT customers in Canada who use the technology for
recreational and business applications, including compliance with lone worker
safety legislation and minimizing the risks for employees working in remote
areas. According to the National Search and Rescue Secretariat, Canada is
comprised of 18 million square kilometres of land and water(1). This area
covers 243,800 kilometres of coastline, 3 oceans and 3 million lakes including
the Great Lakes and the St. Lawrence River system. With one of the world’s
largest areas of responsibility for search and rescue, there are 8 million
square kilometres in Canada which fall outside the reach of traditional
cellular and GSM networks(2).

Recent worldwide rescues initiated with SPOT include a woman in Canada who was
involved in a snowmobile accident and was airlifted after suffering severe
injuries; a lone worker in the U.S. who pressed the SOS button on SPOT after
suffering from a seizure while on a logging job site; and a man in Switzerland
who was transported to a hospital via helicopter after a skiing accident. More
stories from some of the thousands of rescues initiated by SPOT are available
online, searchable by region.

“For nearly a decade, we have dedicated ourselves to offering affordable,
lifesaving technology that people can rely on,” said Jay Monroe, Chief
Executive Officer of Globalstar. “We are proud that SPOT has been universally
accepted as the leader in satellite messaging and that we have been able to
provide peace of mind to families, co-workers and loved ones worldwide. This
5000 rescue milestone is a result of the hard work put in by the entire team at
Globalstar, our partners at GEOS and the Search and Rescue community.”

SPOT customers are currently initiating nearly two rescues a day. SPOT excludes
test messages, false alarms, lost or stolen units and duplicate messages from
rescue count.

The centerpiece of the SPOT family is the award-winning SPOT Gen3(TM), a
global, satellite GPS messenger that provides on or off-the-cellular-grid
messaging, emergency alerts, and GPS tracking. SPOT Trace(TM) is a theft-alert
satellite device that can track anything, anytime, anywhere including cars,
snowmobiles, boats or other valuable gear. For more information on SPOT Gen3
and SPOT Trace, including pricing, promotions and dealer locator, visit
FindMeSPOT.ca.

SPOT Rescue Infographic

To view rescue information in more detail, download this new Infographic which
breaks down worldwide incidents by region and activity.

About Globalstar

Globalstar is a leading provider of mobile satellite voice and data services.
Customers around the world in industries such as government, emergency
management, marine, logging, oil & gas and outdoor recreation rely on
Globalstar to conduct business smarter and faster, maintain peace of mind and
access emergency personnel. Globalstar data solutions are ideal for various
asset and personal tracking, data monitoring, SCADA and IoT applications. The
Company’s products include mobile and fixed satellite telephones, the
innovative Sat-Fi satellite hotspot, Simplex and Duplex satellite data modems,
tracking devices and flexible service packages.

Note that all SPOT products described in this press release are the products of
SPOT LLC, which is not affiliated in any manner with Spot Image of Toulouse,
France or Spot Image Corporation of Chantilly, Virginia. SPOT Connect is a
trademark of SPOT LLC. All other trademarks are the property of their
respective owners.

For more information regarding Globalstar Canada Satellite Co., please visit
www.globalstar.ca.

(1)Source: Public Safety Canada, Quadrennial Search and Rescue Review, Dec.
2013. (section II, Executive Summary).

(2)Source: This stat was calculated based on the CRTC’s estimate that cell
coverage extends to 20% of Canada and that Canada’s total land mass is 9.98
million square kilometers. CRTC report, section 5.5 “Wireless networks cover
approximately 20% of Canada’s geographic land mass”

– END RELEASE – 19/04/2017

For further information:
Media Contact
Caroline McGrath
CMM Communications (for Globalstar Canada Satellite Co.)
cmcgrath@globalstar.ca
416-972-1642

COMPANY:
FOR: GLOBALSTAR CANADA SATELLITE CO.
NYSE SYMBOL: GSAT

INDUSTRY: Telecom – Cable and Satellite Services
RELEASE ID: 20170419CC0023

Press Release from Marketwired 1-866-736-3779

Xtreme Announces Terms of CDN$25,000,000 Substantial Issuer Bid

April 19, 2017 by The Canadian Press

FOR: XTREME DRILLING CORP.
TSX SYMBOL: XDC

Date issue: April 19, 2017
Time in: 8:30 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 19, 2017) –

(All amounts in Canadian dollars)

Xtreme Drilling Corp. (“Xtreme” or the “Company”) (TSX:XDC), today announced
the terms of its previously announced substantial issuer bid (the “Offer”),
pursuant to which Xtreme will offer to purchase for cancellation up to
10,416,667 of its common shares (“Shares”) for an aggregate purchase price not
to exceed CDN$25,000,000. The Offer will be conducted through a “modified Dutch
auction” within a price range of not less than CDN$2.40 per Share and not more
than CDN$2.80 per Share (in increments of CDN$0.05 per Share within that
range). We intend to fund the Offer with available cash on hand.

The “modified Dutch auction” tender process allows shareholders to individually
select the price, within the specified range (and specified increments), at
which they are willing to sell their Shares. When the Offer expires, we will
select the lowest purchase price that will allow us to purchase the maximum
number of Shares properly tendered to the Offer, and not properly withdrawn,
having an aggregate purchase price not exceeding CDN$25,000,000. If Shares with
an aggregate purchase price of more than CDN$25,000,000 are properly tendered
and not properly withdrawn, we will purchase the Shares on a pro rata basis
except that “odd lot” tenders (of holders beneficially owning fewer than 100
Shares) will not be subject to pro-ration. The Offer will not be conditioned on
any minimum number of Shares being tendered to the Offer, but will be subject
to other conditions customary for a transaction of this nature. The Offer will
expire at 5 p.m. Eastern time on June 1, 2017, unless terminated or extended by
Xtreme.

We expect to mail the formal Offer to Purchase, Issuer Bid Circular and other
related documents containing the terms and conditions of the Offer,
instructions for tendering Shares, and the factors considered by Xtreme and its
Board of Directors in making its decision to approve the Offer, among other
things, on or about April 26, 2017. These documents will be filed with the
applicable Canadian Securities Administrators and will be available free of
charge on SEDAR at www.sedar.com and on Xtreme’s website at
www.xtremedrillingcorp.com. Shareholders should carefully read the Offer to
Purchase, Issuer Bid Circular and other related documents prior to making a
decision with respect to the Offer.

Any questions or requests for information may be directed to Computershare
Trust Company of Canada, as the depositary for the Offer, at 1-800-564-6253
(Toll Free – North America) or 1-514-982-7555 (Overseas).

Xtreme’s Board of Directors has authorized the making of the Offer based on a
recommendation of an independent committee of Xtreme’s Board of Directors. None
of Xtreme, its Board of Directors or the depositary makes any recommendation to
any Xtreme shareholder as to whether to tender or refrain from tendering their
Shares under the Offer or as to the purchase price(s) at which such
shareholders may tender Shares under the Offer. Shareholders are urged to
consult their own financial, tax and legal advisors and to make their own
decisions whether to tender or to refrain from tendering their Shares to the
Offer and, if so, how many Shares to tender and at what price or prices.

About Xtreme

Xtreme designs, builds, and operates a fleet of high specification AC drilling
rigs featuring leading-edge proprietary technology. Currently, Xtreme operates
one service line – Drilling Services (XDR) under contracts with oil and natural
gas exploration and production companies and integrated oilfield service
providers in Canada and the United States. For more information about the
Company, please visit www.xtremedrillingcorp.com.

The Offer referred to in this news release has not yet commenced. This news
release is neither an offer to purchase nor a solicitation of an offer to sell
any common shares of Xtreme. Any solicitation and the offer to purchase Shares
by Xtreme will be made pursuant to an offer to purchase, issuer bid circular,
letter of transmittal and related materials that Xtreme will file with
applicable securities authorities and Xtreme will distribute these materials to
its shareholders. Copies of these materials will be available free of charge at
www.sedar.com. These materials will contain important information about the
Offer and Xtreme shareholders are urged to read them carefully.

Cautionary Note Regarding Forward-Looking Statements

This news release contains forward-looking information related to our plans,
objectives, expectations and intentions, including our expectations regarding
the launch, terms and timing of the Offer, that we intend to fund any purchases
of Shares pursuant to the Offer from available cash on hand, the intended
mailing date of the Offer materials, and other statements contained in this
release that are not historical facts. Such forward-looking statements are
predictive in nature and may be based on current expectations, forecasts or
assumptions involving risks and uncertainties that could cause actual outcomes
and results to differ materially from the forward-looking statements
themselves. Such forward-looking statements may, without limitation, be
preceded by, followed by, or include words such as “believes”, “expects”,
“anticipates”, “estimates”, “intends”, “plans”, “continues”, “project”,
“potential”, “possible”, “contemplate”, “seek”, or similar expressions, or may
employ such future or conditional verbs as “may”, “might”, “will”, “could”,
“should” or “would”, or may otherwise be indicated as forward-looking
statements by grammatical construction, phrasing or context. For those
statements, we claim the protection of the safe harbor for forward-looking
statements contained in applicable Canadian securities laws. Forward-looking
statements are not guarantees of future performance and are subject to risks
that could cause actual results to differ materially from conclusions,
forecasts or projections expressed in such statements, including, among others,
risks related to: Xtreme’s future capital requirements, market and general
economic conditions, and its ability to obtain regulatory approvals. These
statements are inherently subject to significant risks, uncertainties and
changes in circumstances, many of which are beyond the control of Xtreme. Our
actual results may differ materially from those expressed or implied by such
forward-looking statements, including as a result of changes in global,
political, economic, business, competitive, market and regulatory factors.
These and other risks and uncertainties, as well as other information related
to Xtreme, are discussed in our public filings at www.sedar.com, including in
our annual MD&A and our Annual Information Form. Forward-looking statements are
provided for the purpose of assisting readers in understanding management’s
current expectations and plans relating to the future. Readers are cautioned
that such information may not be appropriate for other purposes. Except as
required by applicable law, we disclaim any intention or obligation to update
or revise any forward-looking statements, whether as a result of new
information, future events or otherwise.

– END RELEASE – 19/04/2017

For further information:
Xtreme Drilling Corp.
Matt Porter
President and Chief Executive Officer
+1 281 994 4600
ir@xdccorp.com
http://www.xdccorp.com/

COMPANY:
FOR: XTREME DRILLING CORP.
TSX SYMBOL: XDC

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170419CC0025

Press Release from Marketwired 1-866-736-3779

Athabasca Oil Corporation: Statement Regarding Information Circular

April 19, 2017 by The Canadian Press

FOR: ATHABASCA OIL CORPORATIONTSX SYMBOL: ATHDate issue: April 19, 2017Time in: 6:00 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 19, 2017) – Athabasca Oil Corporation
(TSX:ATH) (“Athabasca” or the “Company”) advises that on page 3 of its
Info…

PetroMaroc Update

April 18, 2017 by The Canadian Press

FOR: PETROMAROC CORPORATION PLCTSX VENTURE SYMBOL: PMADate issue: April 19, 2017Time in: 2:00 AM eAttention:
TORONTO, ONTARIO–(Marketwired – April 19, 2017) – PetroMaroc Corporation plc
(TSX VENTURE:PMA), an independent oil and gas company focused on …

Parkland Fuel buying Chevron Canada fuel business for nearly $1.5 billion

April 18, 2017 by The Canadian Press

CALGARY — Fast-growing Parkland Fuel Corp. (TSX:PKI) has struck a $1.5-billion deal to buy Chevron Canada’s downstream fuel business, including 129 retail gas stations in the Vancouver area and the Chevron refinery in Burnaby, B.C.

The Red Deer, Alta.-based company says the new stations will complement its existing 44 Chevron-branded sites in British Columbia and cement its position as one of Canada’s largest fuel retailers with more than 1,800 service stations.

The sale also involves 37 commercial cardlock and three marine fuelling locations, as well as three terminals in B.C. and a wholesale business that includes aviation fuel sales to the Vancouver International Airport.

“I believe we’ve found an opportunity that is an ideal next step for Parkland on its growth trajectory,” said CEO Bob Espey on a conference call.

“I’m certainly excited for the road ahead for Parkland.”

He said the acquisition will support Parkland’s existing operations in B.C., leading to between $35 million and $50 million in annual operating cost savings within three years.

The purchase of the refinery gives Parkland access to the Trans Mountain oil pipeline from Alberta as well as a marine dock on Burrard Inlet that will open new opportunities in fuel imports and exports, Espey said.

Parkland plans to issue 24 million shares to raise $660 million to help finance the Chevron purchase, which is expected to close at the end of the year.

In August, Parkland announced it would pay about US$750 million to acquire the Canadian retail fuel assets of Texas-based CST Brands.

Last March, Parkland bought Esso stations in Saskatchewan and Manitoba as part of a deal by Imperial Oil to sell its remaining 497 Esso retail stations in Canada to five fuel distributors for $2.8 billion.

Follow @HealingSlowly on Twitter.

Dan Healing, The Canadian Press

Note to readers: This is a corrected story. A previous version incorrectly stated that the deal will close in the second quarter of 2017.

Majority of First Nations Support Northern Gateway – Canada Action

June 28, 2017April 18, 2017 by EnergyNow Media

A strong majority of First Nations in Canada are open minded to pipeline and petroleum development. The “no-everything” message from well funded protest groups is not representative of the majority. Here are a couple quotes from this MUST READ article about Northern Gateway. “Most aboriginal communities in northern British Columbia impacted by the Northern Gateway pipeline supported … Read more

Cordy Oilfield Services Inc. Reports Fourth Quarter and 2016 Annual Results

April 18, 2017 by The Canadian Press

FOR: CORDY OILFIELD SERVICES INC.TSX VENTURE SYMBOL: CKKDate issue: April 18, 2017Time in: 7:15 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 18, 2017) –
CORDY OILFIELD SERVICES INC. (the “Corporation” or “Cordy”) (TSX VENTURE:CKK)
released tod…

IMF foresees global economy accelerating to 3.5 pct. in ’17

April 18, 2017 by The Canadian Press

WASHINGTON — A resilient China, rising commodity prices and sturdy financial markets are offering a sunnier outlook for the global economy and helping dispel the gloom that has lingered since the Great Recession ended.

That’s the picture sketched Tuesday by the International Monetary Fund, which predicts that the world economy will grow 3.5 per cent this year, up from 3.1 per cent in 2016. The IMF’s latest outlook for 2017 is a slight upgrade from the 3.4 per cent global growth it had forecast in January.

The IMF expects the U.S. economy to grow 2.3 per cent, up from 1.6 per cent in 2016; the 19-country eurozone to expand 1.7 per cent, the same as last year; Japan to grow 1.2 per cent, up from 1 per cent; and China to expand 6.6 per cent, down from 6.7 per cent in 2016.

“Momentum in the global economy has been building since the middle of last year,” the IMF’s chief economist, Maurice Obstfeld, told reporters. But, he added, “We cannot be sure we are out of the woods.”

The monetary fund’s latest outlook for the economy comes in advance of spring meetings in Washington this week of the IMF, the World Bank and the Group of 20 major economies. The meetings come against the backdrop of a gradually strengthening international picture, especially in many emerging economies, despite resistance to free trade and political unrest in some countries.

For years after the 2008 financial crisis and the Great Recession ended, the global economy remained trapped in what the IMF’s managing director, Christine Lagarde, termed “the New Mediocre.” Banks were weak and reluctant to lend, and deeply indebted governments made growth-killing budget cuts.

The once-super-charged Chinese economy began a long slowdown, driving down global commodity prices and hurting countries from Australia to Zambia that fed raw materials to the world’s second-biggest economy. Plummeting oil prices forced energy companies to slash production.

Now, Lagarde and others say, the outlook is brightening. China’s economy has steadied, thanks to government spending and an easy-money credit boom. Beijing said Monday that its economy grew at a 6.9 per cent annual pace from January to March, the fastest in more than a year. Thanks in part to relief over China’s prospects, global commodity prices have stabilized after plummeting from mid-2014 to early 2016.

Oil prices have surged nearly 40 per cent in the past year, partly because oil-producing countries agreed to curb production.

Financial markets have marched upward. Investors expect the Chinese government to continue supporting economic growth. They also expect President Donald Trump to deliver tax cuts and infrastructure spending that could help boost U.S. economic growth.

The IMF does warn of downside risks to its optimistic forecast. They include “the threat of deepening geopolitical tensions,” the possibility that rising U.S. interest rates will squeeze economic growth and rattle financial markets and the threat that protectionist measures will damage global trade.

Trump campaigned on an “America First” trade policy, vowing to brand China a currency manipulator and to renegotiate — or tear up — the North American Free Trade Agreement with Canada and Mexico. But Bob Baur, chief global economist at Principal Global Investors, noted that Trump has retreated from those threats: His administration declined last week to accuse China of undervaluing its currency. And so far, it has signalled unexpectedly modest goals for rewriting NAFTA.

So the risk that protectionist U.S. policies and trade disputes could disrupt global commerce has “diminished,” Baur said.

Wealthy economies also face deeper problems, in particular chronically weak growth in productivity — the output produced per hour of work — and aging workforces.

Paul Wiseman, The Associated Press

Parkland to Acquire Chevron Canada’s Downstream Fuel Business

April 18, 2017 by The Canadian Press

FOR: PARKLAND FUEL CORPORATION
TSX SYMBOL: PKI

Date issue: April 18, 2017
Time in: 4:26 PM e

Attention:

Transformational Acquisition Strengthens a Premier and Diversified Fuels
Marketing Company and Enhances Canada-wide Network

CALGARY, ALBERTA–(Marketwired – April 18, 2017) –

NOT FOR DISTRIBUTION TO U.S. NEWS WIRE SERVICES OR DISSEMINATION IN THE UNITED
STATES

(All financial figures are approximate and in Canadian dollars unless otherwise
noted)

Parkland Fuel Corporation (“Parkland”) (TSX:PKI) announced today that it has
entered into an agreement with Chevron Canada Limited (“CCL”) to acquire all of
the shares of Chevron Canada R&M ULC, which operates its Canadian integrated
downstream fuel business (the “Acquisition”).

The Acquisition places important British Columbia infrastructure under
experienced Canadian ownership. The business acquired as part of the
Acquisition (collectively, the “Acquired Business”) consists of: i) 129
Chevron-branded retail service stations principally located in Metro Vancouver,
which complement Parkland’s existing 44 Chevron-branded sites in British
Columbia (the “Retail Business”), ii) 37 commercial cardlock and three marine
fueling locations (the “Commercial Business”), iii) a complimentary refinery in
Burnaby, terminals located in Burnaby, Hatch Point, and Port Hardy, British
Columbia, and a wholesale business which includes aviation fuel sales to the
Vancouver International Airport (collectively, the “Supply and Wholesale
Business”).

Subject to satisfaction of customary closing conditions, Parkland will pay
approximately $1,460 million (US$1,100 million), plus an estimated $186 million
in working capital for the Acquired Business.

“This accretive acquisition further strengthens our supply-focused business
model and adds significant scale with the premier Chevron retail brand and
network in British Columbia,” said Bob Espey, President and Chief Executive
Officer of Parkland. “Parkland is acquiring a highly integrated business which
adds significant supply infrastructure and logistics capability to support
Parkland’s existing operations. The refinery in Burnaby is an important asset
to Metro Vancouver and British Columbia and we will continue to operate it with
the capable and experienced professionals who manage the refinery today. We
look forward to welcoming the Chevron team to our company, and to deepening our
relationships in British Columbia.”

Acquisition Highlights

Strategic Rationale for the Acquisition

/T/

— Acquires British Columbia’s premier fuel marketing business and will be

the exclusive distributor of Chevron-branded fuels;
— Adds more than 2.5 billion litres of annual volume and $230 million in
estimated Normalized EBITDA excluding expected synergies;
— Acquires key supply infrastructure (three terminals and a high value
refinery with pipeline access) to significantly enhance Parkland’s
supply advantage;
— Secures Parkland’s position as Canada’s largest fuel retailer by site
count supplying over 1,800 service stations;
— Develops Parkland’s marine logistics capability in a strategically
attractive Vancouver-area waterfront location; and
— The Acquisition, along with the previously announced asset purchase
agreement with Alimentation Couche-Tard Inc. to acquire the majority of
the Canadian business and assets of CST Brands, Inc. (the “CST
Acquisition”) which is expected to close in the second quarter of 2017,
provide Parkland with significant opportunity for synergies.

/T/

Retail and Commercial Businesses

/T/

— Acquires 129 Chevron branded retail service stations, adding 950 million

litres in incremental annual retail fuel volume and strengthening its
position as the largest fuel retailer by site count and the second
largest convenience store operator in Canada pro forma the CST and CCL
acquisitions;
— Adds high quality company-owned retail footprint in Metro Vancouver that
complements Parkland’s existing 44 Chevron-branded retail sites in
British Columbia; and
— Acquires 37 commercial cardlock sites in British Columbia and Alberta,
and three marine fueling stations in Vancouver, adding 370 million
litres in new Commercial volume and complementing the Ultramar branded
cardlock network in Eastern Canada once the CST Acquisition closes.

/T/

Supply and Wholesale Business

/T/

— Acquires a 55 thousand barrel per day (3.7 billion litres per year)

refinery in Burnaby that is highly integrated with the retail,
commercial, and wholesale businesses, as 85% of the refinery’s
production is sold through the acquired marketing assets;
— Acquires three terminal assets in Burnaby, Hatch Point and Port Hardy;
— Acquires a wholesale aviation business serving Vancouver International
Airport (“YVR”);
— Ideally located refinery to serve the British Columbia market as the
largest of only two refineries in the province, and the only one in the
Vancouver supply area;
— Provides exclusive source of Supreme Plus 94 octane gasoline sold
throughout British Columbia; and
— Benefits from a track record of highly reliable operations under CCL’s
ownership.

/T/

Synergies and Accretion

/T/

— Total identified annual run-rate synergies of $35-$50 million, resulting

in total estimated Normalized EBITDA of $265-$280 million including
synergies;
— 30%+ accretion to 2016 distributable cash flow per share (pro-forma the
CST Acquisition) on a run-rate, normalized basis; and
— Pro forma Net Debt to EBITDA of approximately 3.5x with a strong
deleveraging profile; Parkland expects to reduce its leverage ratio to
well within its previous guidance by 2019.

/T/

Other Transaction Details

/T/

— Parkland will invest in the retail operations and apply its expertise as

a leading fuel marketer and convenience store operator to enhance the
customer experience;
— Parkland intends to retain the key management personnel who possess the
refining knowledge and expertise acquired as part of Chevron Canada’s 85
year experience operating the refinery in Burnaby; and
— Parkland commits to continuing Chevron Canada’s active role in community
initiatives.

/T/

Acquisition Financing

The Acquisition and related fees and expenses will be financed with a fully
underwritten financing package including:

/T/

— Approximately $660 million from a bought deal private placement of

common shares in Parkland (“Shares”);
— $268 million drawn on revolving credit facility and $500 million from a
bridge facility, both of which have been fully underwritten by The
Toronto-Dominion Bank and National Bank of Canada as Co-lead Arrangers
and Joint Bookrunners; and
— $40 million of non-debt sources, the majority of which is expected to be
cash flows from operations.

/T/

Parkland expects to replace the bridge facility with alternative longer term
debt prior to the closing of the Acquisition. Furthermore, Parkland intends to
enter into a working capital financing agreement with Merrill Lynch Commodities
to finance the hydrocarbon inventory and receivables, which are estimated to be
$258 million at the close of the Acquisition.

“The scale of the pro-forma business combined with the strong cash flow from
operations and operational synergies expected from the Acquired Business will
further strengthen Parkland’s balance sheet and capital structure,” said Mike
McMillan, Chief Financial Officer. “The transaction financing structure we have
put in place enables Parkland’s pro forma leverage ratio to be approximately
3.5x and is expected to be reduced further in 2019.”

In order to finance a portion of the Acquisition, Parkland has entered into an
agreement with a syndicate of underwriters (the “Underwriters”) bookrun by TD
Securities Inc. and National Bank Financial Inc., to sell approximately 24
million Shares on a bought deal private placement basis. The Shares will be
sold at a price of $27.70 per Share (the “Offering Price”) for gross proceeds
to Parkland of approximately $660 million (the “Offering”).

The Shares will be offered by way of private placement exemptions to accredited
investors in all provinces of Canada, and in the United States on a private
placement basis pursuant to exemptions from the registration requirements of
the United States Securities Act of 1933, as amended. The Shares will be
subject to a four month hold period, under applicable securities laws in
Canada. Closing of the Offering is expected to occur on or about May 9, 2017,
subject to Toronto Stock Exchange and other necessary regulatory approvals.

The Acquisition is subject to the receipt of customary third-party consents and
regulatory approvals, including approval from the Competition Bureau of Canada.
Closing of the Acquisition is expected to be in the Q4 2017.

Update on CST Acquisition

Parkland expects to close the CST transaction in Q2 2017.

Investor Event and Conference Call Information

Parkland Fuel Corporation will host a webcast and conference call on 2:45 p.m.
MT (4:45 p.m. ET) on April 18, 2017 to discuss the Acquisition. Parkland’s
Senior Leadership Team will be available to take questions from securities
analysts, and investors following their formal comments.

Please log into the webcast slide presentation 10 minutes prior to start time
at:

http://edge.media-server.com/m/p/9jdf3htp

To access the conference call by telephone, dial toll-free: 1 844-889-7784
(Conference ID: 10377960). Please connect approximately 10 minutes before the
beginning of the call. The webcast will be available for replay one hour after
the conference call ends. It will remain available at the link above for one
year and will be posted to www.parkland.ca.

A link to the live webcast and investor presentation will be available on the
Investors section of Parkland’s website. http://www.parkland.ca/investors/.

If you are unable to participate in the call, a replay will be available by
dialing 1 855-859-2056 (Conference ID: 10377960) (Canada and USA toll-free).
For international callers, please dial 1 404-537-3406 (Conference ID:
10377960). A transcript of the broadcast will be posted on the website once it
becomes available.

Advisors

BofA Merrill Lynch, TD Securities Inc. and National Bank Financial Inc. are
serving as financial advisors to Parkland. McCarthy Tetrault LLP is serving as
Parkland’s legal advisor for the Acquisition and Bennett Jones LLP is serving
as Parkland’s legal advisor in respect of the Offering and competition matters
relating to the Acquisition.

Forward-Looking Statements

Certain information included herein is forward-looking. Many of these forward
looking statements can be identified by words such as “believe”, “expects”,
“expected”, “will”, “intends”, “projects”, “projected”, “anticipates”,
“estimates”, “continues”, “objective” or similar words and include, but are not
limited to, statements regarding Parkland’s expectation of its future financial
position, business and growth strategies and objectives, sources of growth,
capital expenditures, financial results, future financing and the terms
thereof, future acquisitions and the efficiencies to be derived therefrom,
Parkland’s leverage pro forma the Acquisition, Normalized EBITDA (as defined
herein) of the business acquired in the Acquisition, future projections of
Normalized EBITDA, the contribution to EBITDA and/or Adjusted EBITDA and/or
Normalized EBITDA from the Acquisition, the pro forma site counts, volumes, and
gross margins expected to be derived from the Acquisition and, where applicable
the CST Acquisition, and sources of financing for the Acquisition. Unless
otherwise stated or the context dictates otherwise, the financial outlook and
forward looking metrics contained in this press release are based on the
following assumptions, as applicable, including but not limited to: (i)
Parkland securing sufficient supply of crude oil, including sufficient access
to linespace on the Trans Mountain pipeline; (ii) refining and marketing
margins in Metro Vancouver, Vancouver Island, and the BC Interior remaining
consistent with historic norms; (iii) conducting a planned shutdown and
maintenance of the refinery located in Burnaby, B.C. (“Burnaby Refinery”) in Q1
2018 (“2018 Turnaround”); (iv) maintaining the assets within the forecasted
budget for capital expenditures, particularly those relating to the Burnaby
Refinery; (v) operating the Burnaby Refinery with no unplanned extended outage;
and (vi) operating the Burnaby Refinery at a utilization rate within historic
norms including in respect of fluctuations of refining gross margins, and
planned maintenance downtime and associated expenses.
Parkland believes the expectations reflected in such forward-looking statements
are reasonable but no assurance can be given that these expectations will prove
to be correct and such forward looking statements should not be unduly relied
upon. The forward-looking statements contained herein are based upon certain
assumptions and factors including, without limitation: historical trends,
current and future economic and financial conditions, and expected future
developments. Parkland believes such assumptions and factors are reasonably
accurate at the time of preparing this press release. However, forward-looking
statements are not guarantees of future performance and involve a number of
risks and uncertainties some of which are described in Parkland’s annual
information form and other continuous disclosure documents. Such
forward-looking statements necessarily involve known and unknown risks and
uncertainties and other factors, which may cause Parkland’s actual performance
and financial results in future periods to differ materially from any
projections of future performance or results expressed or implied by such
forward looking statements.
Such factors include, but are not limited to, risks associated with: the
failure to achieve the anticipated benefits of acquisitions, including the
Acquisition and/or the CST Acquisition; the operations of the Burnaby Refinery
assets including compliance with all necessary regulations; competitive action
by other companies; refining and marketing margins; the ability to
cost-effectively secure sufficient supply of crude oil and other raw materials,
including sufficient access to linespace on the Trans Mountain pipeline; the
ability of suppliers to meet commitments; the ability to conduct the 2018
Turnaround as planned in Q1 2018; the ability of management to maintain the
Acquired Business within the forecasted budget for capital expenditures,
particularly those relating to the Burnaby Refinery; the ability to maintain
productive relationships with the labour unions (Unifor and Teamsters) that
represent the majority of the employees at the Burnaby Refinery; failure to
obtain necessary regulatory or other third party consents and approvals
required to complete the Acquisition and/or the CST Acquisition; failure to
complete the Acquisition and/or the CST Acquisition, failure to complete the
Offering, ability to secure alternative sources of funding to the bridge
facility on terms acceptable to Parkland, failure to meet financial,
operational and strategic objectives and plans; general economic, market and
business conditions; industry capacity; failure to realized anticipated
synergies from the CST Acquisition and or the Acquisition, the operations of
Parkland’s assets, competitive action by other companies; the ability of
suppliers to meet commitments; actions by governmental authorities and other
regulators including increases in taxes; changes and developments in
environmental and other regulations; and other factors, many of which are
beyond the control of Parkland.
There is a specific risk that Parkland may be unable to complete the
Acquisition in the manner described in this press release or at all. If
Parkland is unable to complete the Acquisition, there could be a material
adverse impact on Parkland and on the value of its securities. Readers are
directed to, and are encouraged to read, Parkland’s management discussion and
analysis for the year ended December 31, 2016 (the “MD&A”), including the
disclosure contained under the heading “Risk Factors” therein. The MD&A is
available by accessing Parkland’s profile on SEDAR at www.sedar.com and such
information is incorporated by reference herein.

Non-GAAP Financial Measures

This press release refers to certain financial measures that are not determined
in accordance with International Financial Reporting Standards (“IFRS”).
Adjusted EBITDA, Normalized EBITDA, Adjusted Gross Profit, Distributable Cash
Flow, Distributable cash flow per share, Payout Ratio, Earnings Per Share,
Normalized EBITDA, Senior Funded Debt and Total Funded Debt to Credit Facility
EBITDA are not measures recognized under IFRS and do not have standardized
meanings prescribed by IFRS. Other issuers may calculate these non-GAAP
measures differently. Management considers these to be important supplemental
measures of Parkland’s performance and believes these measures are frequently
used by securities analysts, investors and other interested parties in the
evaluation of companies in its industries. See “Non-GAAP financial measures,
reconciliations and advisories” section of the MD&A. Normalized EBITDA is
management’s estimate of the annualized five-year average EBITDA of the
Acquired Business post-2018 Turnaround, based on the annualized average
historical EBITDA of the Acquired Business from 2012-2016 and is subject to the
material factors and assumptions noted above as well as management’s
assumptions regarding: i) crude oil costs and refined product pricing for the
future period (refined product pricing is driven by refined product supply and
demand in Metro Vancouver); and ii) expenses in connection with routine
turnarounds which temporarily increase operating expenses and decreases
throughput and revenue. Normalized EBITDA in respect of the Acquired Business
has been determined in a manner consistent with the manner in which Parkland
determines EBITDA for reporting purposes over the periods referred to.
Investors are encouraged to evaluate each adjustment and the reasons Parkland
considers it appropriate for supplemental analysis. Readers are cautioned,
however, that these measures should not be construed as an alternative to net
income determined in accordance with IFRS as an indication of Parkland’s
performance.
The financial measures that are not determined in accordance with IFRS in this
press release are expressly qualified by this cautionary statement.
Additionally, the estimated annual Adjusted EBITDA contribution from the
Acquired Business and/or the business acquired in the CST Acquisition is based
on the financial statements of CCL and CST respectively, which were prepared in
accordance with United States (U.S.) generally accepted accounting principles
(U.S. GAAP) and converted to Canadian dollars at averaged historical exchange
rates on a quarterly basis. Additionally, readers are directed to, and
encouraged to read, the 2017 Adjusted EBITDA Guidance Range section of
Parkland’s press release dated March 2, 2017 and material factors and
assumptions contained therein. Parkland believes such Parkland believes its
estimation of annual Adjusted EBITDA, Adjusted Gross Profit, and Distributable
Cash Flow per share based on such information is reasonable and but no
assurance can be given that these expectations will prove to be correct and
such figures should not be unduly relied upon. Any forward-looking statements
are made as of the date hereof and Parkland does not undertake any obligation,
except as required under applicable law, to publicly update or revise such
statements to reflect new information, subsequent or otherwise. The
forward-looking statements contained in this press release are expressly
qualified by this cautionary statement.

About Parkland Fuel Corporation

Parkland Fuel Corporation is one of North America’s largest marketers of fuel
and petroleum products. We deliver gasoline, diesel, propane, lubricants,
heating oil and other high-quality petroleum products to motorists, businesses,
households and wholesale customers in Canada and in the United States. Our
mission is to be the partner of choice for our customers and suppliers, and we
do this by building lasting relationships through outstanding service,
reliability, safety and professionalism.

We are unique in our ability to provide customers with dependable access to
fuel and petroleum products, utilizing a portfolio of supply relationships,
storage infrastructure, and third-party rail and highway carriers to rapidly
respond to supply disruptions in order to protect our customers.

To sign up for Parkland news alerts, please go to https://goo.gl/mNY2zj or
visit www.parkland.ca.

– END RELEASE – 18/04/2017

For further information:
Investor Inquiries – French and English
Parkland Fuel Corporation
Ben Brooks
Vice President Treasury & Investor Relations
403-567-2534
Ben.Brooks@parkland.ca
OR
Media Inquiries – French and English
Parkland Fuel Corporation
Annie Cuerrier
Director, Corporate Communications
403-567-2579
Annie.Cuerrier@parkland.ca

COMPANY:
FOR: PARKLAND FUEL CORPORATION
TSX SYMBOL: PKI

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170418CC0090

Press Release from Marketwired 1-866-736-3779

Savanna Announces Receipt of Demand for Payment of Termination Fee

April 18, 2017 by The Canadian Press

FOR: SAVANNA ENERGY SERVICES CORP.TSX SYMBOL: SVYDate issue: April 18, 2017Time in: 1:55 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 18, 2017) – Savanna Energy Services
Corp. (“Savanna”) (TSX:SVY) announces it has received a demand (the “Noti…

Alectra study identifies residential solar storage potential

April 18, 2017 by The Canadian Press

FOR: ALECTRA INC.
Date issue: April 18, 2017Time in: 9:58 AM eAttention:
Report shows value of ‘POWER.HOUSE’ Expansion to customers and the grid
HAMILTON, ON –(Marketwired – April 18, 2017) – Alectra Inc., with the
support of the Independent Electric…

Forent Energy Announces Demand Payment by Its Lender

April 18, 2017 by The Canadian Press

FOR: FORENT ENERGY LTD.
TSX VENTURE SYMBOL: FEN

Date issue: April 18, 2017
Time in: 9:30 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 18, 2017) – Forent Energy Ltd. (TSX
VENTURE:FEN) (“Forent” or the “Company”) announces that, at close of business
April 13, 2017, it received demand repayment from its lender of all amounts
owing thereunder, being approximately $6.8 million, by 5:00 PM April 23, 2017
at which time the lender may enforce its security and appoint a Receiver to
manage the Company’s affairs. Notwithstanding the foregoing, the Company is
continuing to pursue strategic alternatives within the timeline of the notice
period.

Reader Advisory and Note Regarding Forward Looking Information

Certain statements contained within this press release, and in certain
documents incorporated by reference into this document constitute forward
looking statements. These statements relate to future events or future
performance. All statements, other than statements of historical fact, may be
forward looking statements. Forward looking statements are often, but not
always, identified by the use of words such as “seek”, “anticipate”, “budget”,
“plan”, “continue”, “estimate”, “expect”, “forecast”, “may”, “will”, “project”,
“predict”, “potential”, “targeting”, “intend”, “could”, “might”, “should”,
“believe” and similar expressions. These statements involve known and unknown
risks, uncertainties and other factors that may cause actual results or events
to differ materially from those anticipated in such forward looking statements.
In particular, this press release contains the following forward looking
statements pertaining to, without limitation, the following: whether the lender
will enforce security and appoint a Receiver; whether the Company will be
successful in its strategic alternatives efforts.

Readers are cautioned that the foregoing lists of factors are not exhaustive.
The forward looking statements contained in this press release and the
documents incorporated by reference herein are expressly qualified by this
cautionary statement. The forward looking statements contained in this press
release speak only as of the date thereof and FEN does not assume any
obligation to publicly update or revise them to reflect new events or
circumstances, except as may be required pursuant to applicable securities laws.

For more information on the Company, Investors should review the Company’s
registered filings which are available at www.sedar.com.

This news release shall not constitute an offer to sell or the solicitation of
any offer to buy, nor shall there be any sale of these securities in any
jurisdiction in which such offer, solicitation or sale would be unlawful. The
securities offered have not been and will not be registered under the U.S.
Securities Act of 1933, as amended, and may not be offered or sold in the
United States absent registration or applicable exemption from the registration
requirements of the U.S. Securities Act and applicable state securities laws.

– END RELEASE – 18/04/2017

For further information:
Forent Energy Ltd.
Curtis Hartzler
President & CEO
(403) 262-9444 #204
info@forentenergy.com
www.forentenergy.com

COMPANY:
FOR: FORENT ENERGY LTD.
TSX VENTURE SYMBOL: FEN

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170418CC0050

Press Release from Marketwired 1-866-736-3779

Source Energy Services Ltd. completes acquisition of Sand Products

April 18, 2017 by The Canadian Press

FOR: SOURCE ENERGY SERVICES LTD.TSX SYMBOL: SHLEDate issue: April 18, 2017Time in: 9:12 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 18, 2017) –
NOT FOR DISTRIBUTION TO UNITED STATES NEWS WIRE SERVICES OR DISSEMINATION IN
THE UNITED STATES
Sou…

Countdown is on for tow of massive Hebron oil platform to field off Newfoundland

April 18, 2017April 18, 2017 by The Canadian Press

BULL ARM, N.L. — It was made with more concrete than the Empire State Building — and it moves.

Dignitaries cut ceremonial mooring chains on the massive Hebron oil platform Tuesday, marking the wind-up of construction for a $14-billion project that employed more than 7,500 people at its height.

Geoff Parker, senior project manager, said a slip form for the gravity-based structure tanks, which sit mostly under water, used more concrete than the famed New York City skyscraper. The base is 130 metres in diameter, required 132,000 cubic metres of concrete and has 52 well slots.

Combined with the topsides, where about 220 people will live and work, the structure towers 230 metres high and weighs 750,000 tonnes. It will be towed next month from Bull Arm on Trinity Bay to its destination in the Jeanne D’Arc Basin about 350 kilometres southeast of St. John’s.

The platform was designed to handle up to 150,000 barrels of crude a day. There’s a sprawling helipad. And a fibre optic cable will transmit data to a control room in St. John’s that replicates the one on board.

“We’re on track to be setting down the platform in May, then we’ll be drilling in the summer and producing oil by the end of the year,” Parker told reporters.

“This is a large, complex project,” he added, noting that various components were built around the province and the world using cutting-edge technology.

The Hebron oilfield is estimated to contain more than 700 million barrels of oil.

Total expenses almost tripled and oil prices have dropped since the project was first announced 10 years ago at an estimated cost of $5 billion.

The governing Liberals say it will generate more than $10 billion in royalties and benefits over the next 20 years — less than half the estimated $23 billion once hailed by the former Tory government.

Paul Dwyer, the offshore installation manager, said workers logged 40 million hours without a lost-time injury.

He called that an “amazing” achievement on a project that will reap dividends over the next two decades.

“The industry is still growing,” he said in an interview.

Hebron project partners led by ExxonMobil Canada include Chevron Canada, Suncor Energy, Statoil Canada and provincial Crown corporation Nalcor Energy with a 4.9 per cent equity stake.

The province acquired the stake after a battle over revenue sharing between former premier Danny Williams and ExxonMobil.

Hebron will be the fourth producing site off Newfoundland and will offset waning output at Hibernia, Terra Nova and White Rose.

Provincial NDP Leader Earle McCurdy acknowledged it’s a proud milestone for those who pulled off an impressive engineering feat. Still, he said money spent on Hebron was siphoned from other priorities and, with lower oil prices, won’t be quite the anticipated cash cow.

“I think we could have done better on the economic returns from it,” he said in an interview.

“It was based on a high level of optimism about where oil prices would be,” McCurdy said of the deal struck by the former Progressive Conservative government under Williams. It pays minimal royalties in earlier years, until development costs are recovered, in exchange for higher rates later on.

McCurdy also thinks the province needs a clear strategy to prepare for the shift toward cleaner, renewable energy. At least some of the Hebron earnings should be used “to develop technology to minimize the environmental impact and to … minimize our carbon footprint generally,” he added.

Follow @suebailey on Twitter.

Sue Bailey, The Canadian Press

Enbridge Inc. Closes Secondary Offering of Enbridge Income Fund Holdings Inc. Shares; Over-Allotment Option Fully Exercised for Gross Proceeds of Approximately $0.6 Billion

April 18, 2017 by The Canadian Press

FOR: ENBRIDGE INC.TSX SYMBOL: ENBNYSE SYMBOL: ENBAND ENBRIDGE INCOME FUND HOLDINGS INC.TSX SYMBOL: ENFDate issue: April 18, 2017Time in: 8:37 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 18, 2017) –
NOT FOR DISTRIBUTION IN THE UNITED STATES OR…

Augusta Reports Record Revenue for the Year Ended December 31, 2016

April 18, 2017 by The Canadian Press

FOR: AUGUSTA INDUSTRIES INC.TSX VENTURE SYMBOL: AAODate issue: April 18, 2017Time in: 8:30 AM eAttention:
TORONTO, ONTARIO–(Marketwired – April 18, 2017) – Augusta Industries Inc. (the
“Corporation”) (TSX VENTURE:AAO) is pleased to announce that it ha…

L. Brian Timmerman and Timmerman Trust Sell Shares of Ironhorse Oil & Gas Inc.

April 18, 2017 by The Canadian Press

FOR: L. BRIAN TIMMERMAN

Date issue: April 18, 2017
Time in: 7:30 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 18, 2017) – L. Brian Timmerman and
Timmerman Trust (the “Joint Sellers”) announce today that on April 11, 2017,
they sold an aggregate of 1,283,000 common shares (the “Shares”) in the capital
of Ironhorse Oil & Gas Inc. (TSX VENTURE:IOG), having a head office located at
1000, 324 – 8th Street SW, Calgary, Alberta T2P 2Z2 (“Ironhorse”) representing
approximately 4.6% of the issued and outstanding common shares of Ironhorse
(“Ironhorse Shares”).

The Joint Sellers, together with 1927297 Alberta Ltd., a joint actor of the
Joint Sellers, beneficially own and control, directly or indirectly, 2,358,500
Ironhorse Shares, representing approximately 8.46% of the issued and
outstanding Ironhorse Shares. Immediately prior to the sale of the Shares, the
Joint Sellers, together with 1927297 Alberta Ltd., beneficially owned and
controlled 3,806,000 Ironhorse Shares, representing approximately 13.65% of the
outstanding Ironhorse Shares.

The Shares were sold by the Joint Sellers through the facilities of the TSX
Venture Exchange at prices ranging from $0.14 to $0.145 per Share, with an
average price per Share of approximately $0.142 or an aggregate purchase price
of $182,410.

This press release is issued pursuant to National Instrument 62-103 – The Early
Warning System and Related Take-Over Bid and Insider Reporting Issues, which
also requires a report to be filed with regulatory authorities in each of the
jurisdictions in which Ironhorse is a reporting issuer containing information
with respect to the foregoing matters (the “Early Warning Report”). A copy of
the Early Warning Report will appear with Ironhorse’s documents on SEDAR at
www.sedar.com.

SOURCE: L. Brian Timmerman.

– END RELEASE – 18/04/2017

For further information:
For further information, including provision of a copy of
the Early Warning Report upon request:
L. Brian Timmerman, c/o Bennett Jones LLP
4500, 855 2 St S.W., Calgary, Alberta T2P 4K7
Attention: Kelly R. Ford
(403-298-3364)

COMPANY:
FOR: L. BRIAN TIMMERMAN

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170418CC0021

Press Release from Marketwired 1-866-736-3779

Western Energy Services Corp. Demands Payment of Termination Fee from Savanna Energy Services Corp.

April 18, 2017 by The Canadian Press

FOR: WESTERN ENERGY SERVICES CORP.TSX SYMBOL: WRGDate issue: April 18, 2017Time in: 7:30 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 18, 2017) –
NOT FOR DISTRIBUTION TO UNITED STATES NEWSWIRE SERVICES OR FOR DISSEMINATION IN
THE UNITED STATES…

Workers plug Alaska North Slope oil well that leaked gas

April 17, 2017 by The Canadian Press

ANCHORAGE, Alaska — An oil well leaking natural gas on Alaska’s North Slope was successfully plugged by pumping saltwater into the well, according to private and government responders.

The state Department on Environmental Conservation on Monday said the well operated by BP Exploration Alaska Inc., a subsidiary of BP, was “killed” at 3:35 a.m.

The well is five miles from the airport at Deadhorse. Employees on Friday morning discovered uncontrolled natural gas flowing from the top of a well house, a metal structure that looks like a large box over a well.

About 45 minutes later, they determined that the well was spraying a mist of crude oil into the air.

BP reported the leak and set up a joint response team with state, federal and municipal responders.

A weekend statement from the “unified command” said two leaks were detected. Oil was spraying from a leak near the top of the well. Workers contained that leak by activating a safety valve.

Oil droplets likely were contained to 1.5 acres (0.61 hectares) of the drill pad, responders said. They were waiting for the well to be plugged to determine if oil reached nearby snow-covered tundra.

Responders determined the well had risen up to 4 feet (1.22 metres) causing a pressure gauge to break off and preventing responders from pumping material into the well to kill it.

Responders on Saturday night were able to enter the well house and connect hoses to valves. That allowed the bleeding off of gas from space around the well’s below-ground piping and a reduction in gas pressure.

Responders from Boot and Coots Services, a well-control contractor, entered the well house and placed a plug in the above-ground piping. That allowed responders to pump in a solution of methanol and saltwater, killing the well.

The temperature at the site Monday was 21 degrees F (-6.11 Celsius).

The nearest village, Nuiqsut (noo-IK-sit), is 50 miles (80.46 kilometres) away.

___

An earlier version of this story listed an incorrect name for the Alaska Department of Environmental Conservation. The story also incorrectly said federal and state workers, not oil field workers, reduced pressure in the oil well.

The Associated Press

Xtreme Drilling Corp. Announces First Quarter 2017 Operations Update and Conference Call Information

April 17, 2017 by The Canadian Press

FOR: XTREME DRILLING CORP.TSX SYMBOL: XDCDate issue: April 17, 2017Time in: 8:00 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 17, 2017) – Xtreme Drilling Corp.
(“Xtreme”, the “Company”) (TSX:XDC) is pleased to provide a first quarter 2017
oper…

Suncor Energy releases climate report

April 17, 2017 by The Canadian Press

FOR: SUNCOR ENERGY INC.TSX SYMBOL: SUNYSE SYMBOL: SUDate issue: April 17, 2017Time in: 6:00 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 17, 2017) – Suncor today announced the
release of Suncor’s Climate Report: Resilience Through Strategy, wh…

Enbridge Income Fund Holdings Inc. Announces Monthly Dividend

April 17, 2017 by The Canadian Press

FOR: ENBRIDGE INCOME FUND HOLDINGS INC.TSX SYMBOL: ENFDate issue: April 17, 2017Time in: 5:15 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 17, 2017) – Enbridge Income Fund
Holdings Inc. (TSX:ENF) (the Company) announced today that its Board of…

Appulse Corporation: Reporting 2016 results

April 17, 2017 by The Canadian Press

FOR: APPULSE CORPORATIONTSX VENTURE SYMBOL: APLDate issue: April 17, 2017Time in: 4:05 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 17, 2017) – Appulse Corporation
(“Appulse” or “the Corporation”) (TSX VENTURE:APL) today reported revenues of
$…

ZIRCO Announces the Launch of its New Tank Protection Line: See Announcement and Booth No. at ISA Calgary April 19-20th – HERE

June 28, 2017April 17, 2017 by EnergyNow Media

CALGARY, ALBERTA- ZIRCO 1989 (LTD) is delighted to announce the launch of its new tank protection line with their partner FNC Italia. ZIRCO is thrilled to be offering pressure vacuum relief valves (PVRVs), thief hatches, emergency pressure relief valves and flame arrestors. Shairole Henchall, President of ZIRCO commented, “This partnership represents a tremendous opportunity to … Read more

Granite Oil Corp. Announces Monthly Dividend for April, 2017

April 17, 2017 by The Canadian Press

FOR: GRANITE OIL CORP.
TSX SYMBOL: GXO
OTCQX SYMBOL: GXOCF

Date issue: April 17, 2017
Time in: 1:39 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 17, 2017) – GRANITE OIL CORP.
(“Granite”) (TSX:GXO)(OTCQX:GXOCF) is pleased to announce that a dividend of
$0.035 per common share will be paid in cash on May 15, 2017 to shareholders of
record on April 28, 2017. This dividend has been designated as an “eligible
dividend” for Canadian income tax purposes.

– END RELEASE – 17/04/2017

For further information:
Granite Oil Corp.
Michael Kabanuk
President & CEO
(587) 349-9123

COMPANY:
FOR: GRANITE OIL CORP.
TSX SYMBOL: GXO
OTCQX SYMBOL: GXOCF

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170417CC0031

Press Release from Marketwired 1-866-736-3779

Hydrogen fuel cell cars face obstacle: few fueling stations

April 17, 2017 by The Canadian Press

DETROIT — Hydrogen fuel cell cars could one day challenge electric cars in the race for pollution-free roads — but only if more stations are built to fuel them.

Honda, Toyota and Hyundai have leased a few hundred fuel cell vehicles over the past three years, and expect to lease well over 1,000 this year. But for now, those leases are limited to California, which is home to most of the 34 public hydrogen fueling stations in the U.S.

Undaunted, automakers are investing heavily in the technology. General Motors recently supplied the U.S. Army with a fuel cell pickup, and GM and Honda are collaborating on a fuel cell system due out by 2020. Hyundai will introduce a longer-range fuel cell SUV next year.

“We’ve clearly left the science project stage and the technology is viable,” said Charles Freese, who heads GM’s fuel cell business.

Like pure electric cars, fuel cell cars run quietly and emission-free. But they have some big advantages. Fuel cell cars can be refuelled as quickly as gasoline-powered cars. By contrast, it takes nine hours to fully recharge an all-electric Chevrolet Bolt using a 240-volt home charger. Fuel cells cars can also travel further between fill-ups.

But getting those fill-ups presents the biggest obstacle. Fueling stations cost up to $2 million to build, so companies have been reluctant to build them unless more fuel cell cars are on the road. But automakers don’t want to build cars that consumers can’t fuel.

The U.S. Department of Energy lists just 34 public hydrogen fueling stations in the country; all but three are in California. By comparison, the U.S. has 15,703 public electric charging stations, which can be installed for a fraction of the cost of hydrogen stations. There are also millions of garages where owners can plug their cars in overnight.

As a result, U.S. consumers bought nearly 80,000 electric cars last year, but just 1,082 fuel cell vehicles, according to WardsAuto.

That’s why automakers will keep hedging their bets and offer electric vehicles alongside hydrogen ones.

Honda began leasing the 2017 Clarity fuel cell sedan earlier this year; about 100 are already on the road. At this week’s New York Auto Show, the company also introduced electric and plug-in hybrid versions of the Clarity.

The plug-in hybrid can go 42 miles in electric mode before a small gas engine kicks in, Honda says. The all-electric Clarity can go 111 miles on a charge. Both will go on sale later this year.

“We think going forward the powertrain market is going to be very diverse,” said Steve Center, vice-president of the environmental business development office at American Honda.

Hyundai’s Genesis luxury brand also blended technology with its GV80 SUV prototype, which was revealed in New York. The GV80 is a plug-in fuel cell vehicle, which means it would get power from stored electricity as well as hydrogen. It’s not clear when — or if — the GV80 will go on sale.

Fuel cell cars create electricity to power the battery and motor by mixing hydrogen and oxygen in the specially treated plates that combine to form the fuel cell stack.

The technology isn’t new. GM introduced the first fuel cell vehicle, the Electrovan, in 1966. It only seated two; the back of the van housed large steel tanks of hydrogen and oxygen. It went about 150 miles between refuelings, and its hydrogen tank exploded on at least one occasion.

Advances in hydrogen storage, fuel cell stacks and batteries have allowed engineers to significantly shrink those components to fit neatly inside a sedan. Oxygen is now collected from the air through the grille, and hydrogen is stored in aluminum-lined, fuel tanks that automatically seal in an accident to prevent leaks. Reducing the amount of platinum used in the stack has made fuel cell cars less expensive.

Honda’s new Clarity can go 366 miles between fuelings, the longest range in the industry.

The Clarity leases for $369 per month for 36 months. That’s more than the $354 monthly lease payment for the Chevrolet Bolt electric. But Honda, Toyota and Hyundai are all throwing in free hydrogen refuelling . It costs between $13 and $16 per kilogram for hydrogen, or up to $80 to fill the Clarity’s 5-kilogram capacity, according to the U.S. Energy Department.

Even with that perk, analysts think sales of fuel cell vehicles will be limited until more fueling stations are built. But carmakers will still invest in fuel cells. GM’s Freese says there are many applications beyond cars, including unmanned, deep-sea vehicles or backup home power systems.

“One of the reasons global car companies do something like this is they want to have a finger in the pie. Should we suddenly have to shift over, they want to be able to do it,” said Jack Nerad, an executive market analyst with Kelley Blue Book.

The number of fueling stations could also grow quickly if automakers partner with governments and energy companies, as they have done in California. Earlier this year, 13 companies — including Shell and BMW — formed a council to accelerate the adoption of hydrogen as a transportation fuel.

Heather McLaughlin of San Ramon, California, was one of the first customers to lease a 2017 Clarity. She says she prefers a fuel cell car over an electric because she can refuel it in minutes. And one fill-up a week more than covers her 50-mile daily commute to Benicia, where she serves as the city attorney.

She recently drove the Clarity to Southern California and found plenty of stations along her route.

“I like the innovation,” said McLaughlin. “It helps if we can have more of these on the road.”

Dee-Ann Durbin, The Associated Press

Aveda Transportation and Energy Services Announces Restricted Share Unit Award Grants

April 17, 2017 by The Canadian Press

FOR: AVEDA TRANSPORTATION AND ENERGY SERVICESTSX VENTURE Symbol: AVEDate issue: April 17, 2017Time in: 12:19 PM eAttention:
CALGARY, AB –(Marketwired – April 17, 2017) – Aveda Transportation and
Energy Services Inc. (“Aveda” or the “Company”) (TSX VE…

Crescent Point Energy Confirms April 2017 Dividend

April 17, 2017 by The Canadian Press

FOR: CRESCENT POINT ENERGY CORP.
TSX SYMBOL: CPG
NYSE SYMBOL: CPG

Date issue: April 17, 2017
Time in: 11:38 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 17, 2017) – Crescent Point Energy Corp.
(“Crescent Point” or the “Company”) (TSX:CPG)(NYSE:CPG) confirms that the
dividend to be paid on May 15, 2017, in respect of April 2017 production, for
shareholders of record on April 30, 2017, will be CDN$0.03 per share.

These dividends are designated as “eligible dividends” for Canadian income tax
purposes. For U.S. income tax purposes, Crescent Point’s dividends are
considered “qualified dividends.”

Crescent Point is a leading North American light and medium oil producer that
seeks to maximize shareholder return through its total return strategy of
long-term growth plus dividend income.

CRESCENT POINT ENERGY CORP.

Scott Saxberg, President and Chief Executive Officer

Crescent Point shares are traded on the Toronto Stock Exchange and New York
Stock Exchange, both under the symbol CPG.

– END RELEASE – 17/04/2017

For further information:
Crescent Point Energy Corp.
Ken Lamont
Chief Financial Officer
(403) 693-0020 or Toll free (U.S. & Canada): 888-693-0020
(403) 693-0070 (FAX)
OR
Crescent Point Energy Corp.
Brad Borggard
Vice President, Corporate Planning and Investor Relations
(403) 693-0020 or Toll free (U.S. & Canada): 888-693-0020
(403) 693-0070 (FAX)
www.crescentpointenergy.com

COMPANY:
FOR: CRESCENT POINT ENERGY CORP.
TSX SYMBOL: CPG
NYSE SYMBOL: CPG

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170417CC0024

Press Release from Marketwired 1-866-736-3779

Augusta provides market update and announces its participation at Discovery 2017

April 17, 2017 by The Canadian Press

FOR: AUGUSTA INDUSTRIES INC.TSX VENTURE SYMBOL: AAODate issue: April 17, 2017Time in: 9:26 AM eAttention:
Ontario Centres of Excellence (OCE) selected FOX-TEK to participate in the
Business-to-Government Initiative
TORONTO, ONTARIO–(Marketwired – Apri…

FREE to Attend: Low Carbon Innovation Forum – Global Petroleum Show 2017 – See Details HERE

June 28, 2017April 16, 2017 by EnergyNow Media

The petroleum industry faces one of its greatest challenges as the world moves towards a low carbon economy and the global social licence to produce hydrocarbons becomes more complex by each passing day. The energy producers are in a constant in a state of evolution, and investing in new technologies to produce more hydrocarbons, lower … Read more

Specialized Desanders – The Most Trusted Way to Reduce Expensive Sand Damage

June 28, 2017April 16, 2017 by EnergyNow Media

Sand is an extremely destructive force in the oil and gas industry. It puts your people, your production and your profits all at risk. Headquartered in Calgary, Alberta, Specialized Desanders has two field offices in the province, as well as one in Pennsylvania. It is the most trusted sand management solution. Innovation involves exploring novel … Read more

Premier Clark boasts about B.C.’s overall low jobless rate, but rural areas struggle

April 16, 2017 by The Canadian Press

VICTORIA — Premier Christy Clark often highlights the fact British Columbia has the lowest jobless rate in Canada, but rural and remote areas in the province are struggling with major industry downturns and job losses.

The power of jobs to support families and build strong communities is a major theme in the Liberal leader’s bid for re-election on May 9, but some mayors say high unemployment is tearing at the fabric of their communities.

“I would challenge this government to really open its eyes and look at what’s going on in our small community,” said Shirley Ackland, the mayor of Port McNeill in northern Vancouver Island. “You can’t live in the north island if there are no jobs here.”

She said sawmill closures have hurt Port McNeill, where 80 per cent of residents are dependent on the forest industry for work.

Merritt Mayor Neil Menard said a sawmill closure and layoffs at another lumber mill resulted in the loss of about 350 jobs in the past 18 months.

“The situation here in this particular area as far as employment is concerned is not good,” he said. “I don’t think we have the best economy in the country. In the Interior, we’ve got a lot of struggles going on.”

Last month, Clark was in Merritt to introduce the government’s rural economic development strategy, which included $40 million to expand high-speed Internet service and build infrastructure in rural B.C.

Steve Thomson, forests, lands and natural resource operations minister, said the government’s strategy recognizes the significance of rural communities to B.C.’s economy, mentioning the Site C dam, potential liquefied natural gas projects and the emergence of a technology sector as job creators.

“Every community benefits when our rural communities are strong,” he said.

Thomson said the strategy is focused on building, strengthening and diversifying rural economies, which is especially the case with the forest industry and B.C.’s attempts to develop new lumber markets in Asia. A renewed Canada-United States softwood lumber agreement is another top priority, Thomson said.

The government’s 2017-18 budget, which was not passed by the legislature, also included an extension to 2020 of an annual $25 million dividend fund for rural community projects.

But Fort Nelson Mayor Bill Streeper said the rural strategy failed to recognize the prolonged downturn in the oil and gas industry, which is causing people to leave town to look for work.

He said the council of the Northern Rockies Regional Municipality recently introduced severe austerity measures to curtail community spending, including offering its summer student jobs to unemployed local residents.

Since January, when BC Stats pegged the jobless rate in the northeast at 10.5 per cent, the picture has brightened with an upswing in the oil and gas industry. The most recent numbers for March set the jobless rate in the region at 6.5 per cent.

But the rate jumped to 10 per cent in the Cariboo region. The North Coast-Nechako, Thompson-Okanagan and Kootenay regions all registered slight dips, but still range between 6.4 per cent and 8.3 per cent.

The provincewide rate was 5.4 per cent in March. It’s five per cent in the Lower Mainland and southwest B.C., and 5.6 per cent on Vancouver Island and the central coast.

Quesnel Mayor Bob Simpson said average four-bedroom homes in his Cariboo community can be bought for $170,000, but few people can afford to buy.

The former NDP member of the legislature and forest company executive said the government provided infrastructure funding for Quesnel but the area’s pulp mills and sawmills are hurting.

“The jobs aren’t here. That’s what our struggle is,” he said. “Where’s the plan to help us with our core economy so that people can get meaningful employment?”

Simpson said the government chose to pursue the LNG industry at the expense of forestry.

Clark touted 18 potential LNG export plants as an economic bonanza during the 2013 election campaign, but cooling natural gas markets have resulted in only a woodfibre LNG plant at Squamish proceeding to the start-up phase. A proposed $36-billion Pacific NorthWest project near Prince Rupert is waiting for a final investment decision.

Dirk Meissner, The Canadian Press

Northeastern B.C. towns see Montney natural gas drilling recovery

April 16, 2017 by The Canadian Press

CALGARY — Increasingly empty industrial yards around the northeastern B.C. city of Fort St. John are a welcome sign for Jennifer Moore.

Moore, a regional economic development officer, says the return of parked natural gas drilling rigs and related equipment to the field shows that a recovery is underway for one of Canada’s biggest new energy plays.

Fort St. John sits atop the Montney, a natural gas-bearing formation that straddles the B.C.-Alberta border. Like the oilsands hub of Fort McMurray, its fortunes are closely tied to energy prices.

And with natural gas prices weakened by rising U.S. supplies, Fort St. John and neighbouring communities have witnessed a grinding two-year slowdown.

“It’s been a little scary here,” said Moore, who works for the North Peace Economic Development Commission.

“As you drove around the community industrial areas, you saw a lot of iron parked in yards, and that’s not a good thing. Pipe, equipment, trucks … the majority was parked in town.”

Industry players say that while gas prices are still weak, rich finds in the Montney and the prospect of new pipelines are helping to revive exploration.

According to the online trade publication BOE Report, 335 wells have targeted the Montney in the first quarter of this year. That’s a hopeful sign after drilling fell to 746 wells for all of 2016 from a peak of 1,321 in 2014.

The northeastern B.C. unemployment rate dropped to 6.5 per cent in March from 10.5 per cent in December. At the height of the boom in 2014, it registered as less than 3.5 per cent.

“People are feeling more optimistic,” Moore said. “Cautiously optimistic.”

Energy executives say the Montney’s prolific production, unlocked with horizontal drilling and hydraulic fracturing technology, makes it the most profitable natural gas play in Canada. It provides about one-quarter of Canada’s current natural gas output.

In a recent report, Desjardins Capital Markets said the Montney has proven its quality, with growth now limited mainly by insufficient pipeline space to carry away its growing bounty.

But plans are being filed to bring more Montney gas to market. They include TransCanada’s mainline pipeline system from Alberta to Ontario and its new North Montney Mainline through northeastern B.C., as well as through an expansion of the rival Alliance Pipeline that runs from the Montney region to Chicago.

“Pipelines are being expanded because people can see we’ve got an economic play here,” said Jeff Tonken, CEO of Birchcliff Energy of Calgary, which produces Montney gas and light oil on the Alberta side of the border and has signed contracts for more pipeline space.

Calgary-based Encana (TSX:ECA) has said it wants to nearly double its Montney gas output to 1.2 billion cubic feet per day by 2019, while its associated Montney output of liquids such as condensate and propane is expected to grow by five times to 70,000 barrels per day.

Moore said she expects steady growth going forward, adding it’s unlikely the region will return to the “hair-on-fire” boom of 2014 because of a drilling timeout by producer Progress Energy, owned by Malaysian energy giant Petronas.

Progress has reduced its contracted drilling fleet in northeastern B.C. to one rig from more than 20 in recent years, observers say, as it waits for a final investment decision on its parent company’s Pacific NorthWest liquefied natural gas (LNG) project near Prince Rupert, B.C.

That project would chill and ship up to 3.2 billion cubic feet per day of natural gas to energy-hungry customers in Asia. But it has been delayed by internal reviews and slumping LNG prices.

The Montney production bulge and lack of room on pipe from Western Canada has hurt gas prices at the main Alberta trading hub compared with U.S. prices.

TD Securities says it expects Canadian gas to sell for as much as US$1 less per thousand cubic feet than U.S. gas over the next four years because of “market access challenges.” It’s a significant disadvantage given that U.S. gas is now selling for just over US$3 per thousand cubic feet.

But producers point out their returns are also boosted by condensate — a light oil produced with the gas. Condensate has a geographic advantage. It sells in Edmonton for near-New York benchmark crude oil prices because it is used to dilute oilsands bitumen for pipeline transport.

Gerry Goobie, principal with consultancy Gas Processing Management Inc., estimates Alberta and B.C. condensate production has risen from 181,000 barrels per day in 2014 to 260,000 bpd in 2016, with most of the increase coming from the Montney.

Follow @HealingSlowly on Twitter.

Dan Healing, The Canadian Press

Husky Signs Agreement for New Exploration Block Offshore China

April 13, 2017 by The Canadian Press

FOR: HUSKY ENERGY INC.
TSX Symbol: HSE

Date issue: April 13, 2017
Time in: 8:00 PM e

Attention:

CALGARY, AB –(Marketwired – April 13, 2017) – Husky Energy (TSX: HSE) has
signed a Production Sharing Contract (PSC) for a new exploration block
offshore China.

Block 16/25 is located in the Pearl River Mouth Basin, about 150 kilometres
southeast of the Hong Kong Special Administrative Region.

The Company expects to drill two exploration wells on the shallow water block
during the 2018 timeframe, in conjunction with two planned exploration wells
at the nearby exploration Block 15/33.

Husky is the operator of both blocks during the exploration phase, with a
working interest of 100 percent. In the event of a commercial discovery, its
partner CNOOC Limited may assume a participating interest of up to 51 percent
during the development and production phase.

FORWARD-LOOKING STATEMENTS

Certain statements in this news release are forward-looking statements and
information (collectively “forward-looking statements”), within the meaning of
the applicable Canadian securities legislation, Section 21E of the United
States Securities Exchange Act of 1934, as amended, and Section 27A of the
United States Securities Act of 1933, as amended. The forward-looking
statements contained in this news release are forward-looking and not
historical facts.

Some of the forward-looking statements may be identified by statements that
express, or involve discussions as to, expectations, beliefs, plans,
objectives, assumptions or future events or performance (often, but not
always, through the use of words or phrases such as “will likely result”, “are
expected to”, “will continue”, “is anticipated”, “is targeting”, “estimated”,
“intend”, “plan”, “projection”, “forecast”, “guidance”, “could”, “may”,
“would”, “aim”, “vision”, “goals”, “objective”, “target”, “schedules” and
“outlook”). In particular, forward-looking statements in this news release
include, but are not limited to, references to the Company’s drilling
expectations.

Although the Company believes that the expectations reflected by the
forward-looking statements presented in this news release are reasonable, the
Company’s forward-looking statements have been based on assumptions and
factors concerning future events that may prove to be inaccurate. Those
assumptions and factors are based on information currently available to the
Company about itself and the businesses in which it operates. Information used
in developing forward-looking statements has been acquired from various
sources including third-party consultants, suppliers, regulators and other
sources.

Because actual results or outcomes could differ materially from those
expressed in any forward-looking statements, investors should not place undue
reliance on any such forward-looking statements. By their nature,
forward-looking statements involve numerous assumptions, inherent risks and
uncertainties, both general and specific, which contribute to the possibility
that the predicted outcomes will not occur. Some of these risks, uncertainties
and other factors are similar to those faced by other oil and gas companies
and some are unique to the Company.

The Company’s Annual Information Form for the year ended December 31, 2016 and
other documents filed with securities regulatory authorities (accessible
through the SEDAR website www.sedar.com and the EDGAR website www.sec.gov)
describe risks, material assumptions and other factors that could influence
actual results and are incorporated herein by reference.

Any forward-looking statement speaks only as of the date on which such
statement is made, and, except as required by applicable securities laws, the
Company undertakes no obligation to update any forward-looking statement to
reflect events or circumstances after the date on which such statement is made
or to reflect the occurrence of unanticipated events. New factors emerge from
time to time, and it is not possible for management to predict all of such
factors and to assess in advance the impact of each such factor on the
Company’s business or the extent to which any factor, or combination of
factors, may cause actual results to differ materially from those contained in
any forward-looking statement. The impact of any one factor on a particular
forward-looking statement is not determinable with certainty as such factors
are dependent upon other factors, and the Company’s course of action would
depend upon its assessment of the future considering all information then
available.

– END RELEASE – 13/04/2017

For further information:

For further information, please contact:

Investor Inquiries:

Rob Knowles
Manager, Investor Relations
Husky Energy Inc.
587-747-2116

Media Inquiries:

Mel Duvall
Manager, Media & Issues
Husky Energy Inc.
403-513-7602

COMPANY:
FOR: HUSKY ENERGY INC.
TSX Symbol: HSE

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170413CC020

Press Release from Marketwired 1-866-736-3779

ATCO Recognized for Exceptional Emergency Response in Fort McMurray

April 13, 2017 by The Canadian Press

FOR: ATCO LTD.
TSX SYMBOL: ACO.X
TSX SYMBOL: ACO.Y

Date issue: April 13, 2017
Time in: 6:10 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 13, 2017) – ATCO (TSX:ACO.X)(TSX:ACO.Y)
and its people were recently recognized for their exceptional commitment to
safety during and in the months following the 2016 Fort McMurray Wildfires at
the 2017 Canadian Gas Association (CGA) Operations, Engineering and Integrity
Conference in Halifax, Nova Scotia. The CGA honoured ATCO with the President’s
Safety Award for Excellence, a unique, never-before presented accolade
acknowledging the company’s work supporting the community and its customers
through the crisis.

“This was truly an unprecedented, cross-company effort that brought people from
across our enterprise together as one team, and we are tremendously proud of
the work they have done,” said George Lidgett, Managing Director, Pipelines &
Liquids with ATCO. “Their tireless efforts during and after the crisis are a
testament to the ATCO Heart and Mind – going far above and beyond the call of
duty for our customers.”

Within hours of the community’s evacuation, ATCO had opened the doors of its
Creeburn Lake Lodge to fleeing residents and hundreds of the company’s
highly-skilled employees were mobilized to provide critical natural gas and
electricity infrastructure support. In the largest coordinated response in
ATCO’s history, more than 650 of its people came together to assist evacuees,
assess damage, make repairs and restore essential services.

From keeping water pumping stations and telecommunications sites energized, to
delivering temporary natural gas to the Regional Emergency Operations Centre,
ensuring key infrastructure remained operational was crucial in enabling
emergency responders to safely fight the blaze and helped pave the way for
families to return home. On the ground from the very beginning of the crisis,
the people of ATCO completed all this vital work without a single lost-time
injury.

As residents began returning, teams of ATCO’s people were there welcoming them,
answering questions and providing reassurance when they needed it the most. At
two ATCO meal camps, established to provide a warm bite to eat for returning
members of the community, a small team of company volunteers served up more
than 56,000 meals over just eight days.

The President’s Safety Award for Excellence is the third such accolade ATCO has
received for its response in Fort McMurray. In January 2017, ATCO was honoured
with both the Alberta Emergency Management Agency’s Emergency Management
Achievement Award and the Edison Electric Institute’s Emergency Recovery Award.

– END RELEASE – 13/04/2017

For further information:
Media Inquiries:
Danielle Brown
Manager, External Communications
(780) 420-5682

COMPANY:
FOR: ATCO LTD.
TSX SYMBOL: ACO.X
TSX SYMBOL: ACO.Y

Press Release from Marketwired 1-866-736-3779

Titan Logix Corp. Reports Fiscal 2017 Second Quarter Financial Results and Announces Change of Directors

April 13, 2017 by The Canadian Press

FOR: TITAN LOGIX CORP.
TSX VENTURE SYMBOL: TLA

Date issue: April 13, 2017
Time in: 5:55 PM e

Attention:

EDMONTON, ALBERTA–(Marketwired – April 13, 2017) – Titan Logix Corp., (TSX
VENTURE:TLA) (“Titan” or the “Company”), a high technology company specializing
in advanced technology fluid management solutions, announces its results for
the second quarter ended February 28, 2017 and a change to the Company’s board
of directors.

/T/

Financial Highlights Summary
(in Canadian dollars)

—————————————————————————-

Three months ended Six months ended
—————————————————————————-
February February 29, February February 29,
28, 2017 2016 28, 2017 2016
—————————————————————————-
Revenue $ 872,145 $ 945,112 $ 1,695,804 $ 2,522,899
—————————————————————————-
Gross profit (GP) $ 348,702 $ 169,422 $ 621,774 $ 779,172
—————————————————————————-
GM % 40% 18% 37% 31%
—————————————————————————-
Operating loss before
other items and income $ (344,026) $ (1,000,345) $ (705,045) $ (1,503,515)
tax
—————————————————————————-
Net loss before income
tax $ (326,923) $ (966,702) $ (308,129) $ (1,434,213)
—————————————————————————-
Net loss $ (326,923) $ (658,805) $ (308,129) $ (1,009,660)
—————————————————————————-
EPS (diluted) $ (0.01) $ (0.03) $ (0.01) $ (0.04)
—————————————————————————-

—————————————————————————-
Financial Position As at February 28 2017 As at August 31, 2016
—————————————————————————-
Working capital $ 15,551,883 $ 15,860,627
—————————————————————————-
Total assets $ 17,315,306 $ 17,701,465
—————————————————————————-
Long-term liabilities $ 30,288 $ 91,058
—————————————————————————-
Total equity $ 16,846,926 $ 17,042,206
—————————————————————————-

/T/

“Our product development initiatives to enhance the market leading Titan Brand
are progressing as planned,” said CEO, Douglas Carruthers. “Our engineering and
sales teams are targeting new product releases in the final quarter of this
fiscal year. I am pleased Titan’s existing product sales are meeting our
expectations in this slower market.”

QUARTERLY HIGHLIGHTS

/T/

— Revenues were $872,145 for the second quarter of fiscal 2017 ended

February 28, 2017, an increase over the revenues of each of the last
three quarters, which were $823,659, $706,279 and $743,622 respectively.

— Gross profit as a percentage of sales is recovering and trending towards

previously experienced levels. The gross margin for the second quarter
of fiscal 2017 was 40%, an increase from the last three quarters which
were 33%, 2% and 13% respectively.

— Operating expenses for the second quarter of fiscal 2017 decreased to

$692,728 compared to the fiscal 2016 comparable second quarter’s
expenses of $1,169,767, reflecting management’s cost reduction
initiatives.

— Net loss for the second quarter of fiscal 2017 decreased to $326,923

compared to the fiscal 2016 comparable second quarter’s net loss of
$658,805.

— Product development continued with positive results on the development

of Titan’s next generation of products and other high potential
products.

/T/

Titan Logix Corp.’s revenue is largely derived from sales of its Guided Wave
Radar product line of technologies employed to automate essential measurement
and control processes safely and efficiently. These technologies are sold
primarily into the mobile tanker truck market, servicing upstream/midstream
customers and designated as Titan’s “On the Road” solution offering. Product
revenue is derived from sales throughout Canada and the U.S. The Company’s
revenue for the second quarter of fiscal 2017 ended February 28, 2017 decreased
by $72,967 or 8% to $872,145, as compared to $945,112 for the comparable three-
month period in fiscal 2016. Revenues for the first six months of fiscal 2017
decreased by 33% to $1,695,804 from sales of $2,522,899 in the comparative
period. This decrease in revenue in the quarter and year-over-year reflects
continued weaker demand for the Company’s products in Canada and the U.S.
resulting from lower oil and gas prices.

Cost of sales decreased by $252,247 or 33% to $523,443 in the second quarter of
fiscal 2017, and decreased by $669.697 or 38% to $1,074,030 for the six-month
period ended February 28, 2017. The lower cost of sales was due to reduced
product shipments, a decrease in technical service and support engineering
related costs, and labour savings achieved due to a reduction in the workforce.
These savings partially offset production overhead costs related to spare
capacity of the production facility.

The operating loss before other items and income taxes was $344,026 for the
current quarter and $705,045 for the first six months of fiscal 2017. This
compares to an operating loss before other items and income taxes of $1,000,345
and $1,503,515 respectively in the comparative prior periods of fiscal 2016.
The improvement in the current fiscal quarter and year-to-date is primarily
attributable to the reduction in total expenses, including general and
administration, marketing and sales and engineering, and to a lesser degree the
reduction in production costs included in cost of sales and the resulting
improvement in gross profit. Due to cost reduction initiatives in the prior
fiscal year total expenses decreased by $477,039 in the current fiscal quarter
and $955,868 year-over-year. The operating loss reduction was partially offset
by a decrease in the gain on foreign exchange in the second quarter and first
six months of fiscal 2017 as compared to the previous year’s comparable
periods. Despite significant improvements in its cost structure in the current
fiscal quarter and year-over-year the Company incurred an operating loss,
largely due to continued weaker demand for the Company’s products and the
resulting decrease in revenues.

The net loss in the second quarter of fiscal 2017 was $326,923 ($0.01 loss per
diluted share) compared to a net loss of $658,805 ($0.03 loss per diluted
share) for the comparable period of fiscal 2016. The net loss for the second
quarter of the previous year was reduced by an income tax recovery of $307,897.
There was no income tax recovery recorded in fiscal 2017 due to uncertainties
of the realization of tax loss carry forwards. Net loss and comprehensive loss
in fiscal 2017’s first six months was $308,129 ($0.01 per diluted share) after
tax, compared to a loss of $1,009,660 ($0.04 per diluted share) after tax
reported for the first six months of fiscal 2016. This reduced net loss is tied
to the decrease in operating expenses. In addition, the Company recorded a gain
on sale of assets of $310,963 in the first six months of fiscal 2017 related to
the sale of the TPZ 3310 and 3500 controller product lines sold in conjunction
with the closing of Titan’s under performing Saskatchewan warehouse and service
facility. The net loss for the first six months of the previous year was
reduced by an income tax recovery of $424,553.

Business Outlook

Titan’s revenue from its current primary market – mobile tank gauging for the
crude oil industry – is linked to the economic conditions of the energy
industry and the level of drilling activity. The oilfield fluid transport
market focuses on the transportation of various liquids involved in oilfield
operations such as well fracturing chemicals, produced water, waste liquids,
and crude oil. New drilling activity employs mobile tankers to deliver
necessary process fluids to well sites. The initial well head activity requires
offsite transfer of process water for treatment or disposal. The production
well heads not directly connected to pipeline networks require mobile transfer
of crude oil to pipeline terminals and processing. Each stage stimulates mobile
tanker activity. These liquids are transported in various mobile tankers. Each
of these tankers requires a level measurement and overfill prevention system to
enable rolling-stock inventory management, ensure against overfills (which
would result in high-impact environmental incidents), protect equipment against
damage, improve the efficiency of the operation and help ensure driver safety.
Titan’s TD80(TM) provides this functionality.

The 2016-17 recovery of the market price of WTI Crude Oil from the 2014 extreme
lows is resulting in some uptick in U.S. and Canadian drilling activity as
operators increase their drilling programs. However, the oil price collapse in
2014, stranded a significant backlog on dealer lots of tanker trucks and
trailers suitably equipped with level gauges. This backlog must be absorbed
before the new tanker construction market will begin to recover. Titan is
seeing a slight pickup in its customer’s activity in reaction to the higher and
more stable commodity prices; however, there are no short-term expectations of
significant improvements to revenues. Titan continues to maintain its market
share for level measurement and control devices in a significantly smaller
crude oil tanker construction market in the face of continuing low crude oil
prices. The Company follows oil rig drilling activity and crude oil prices as a
long-range market indicator for its forecasting.

Titan’s proprietary TD80/Finch II/RCM technologies continue to be widely
accepted. Leveraging Titan’s large install base and market share, the Company
is focused on generating new revenue stream opportunities via existing tanker
retrofit sales and by exploring new market alternatives for product sales in
other than crude oil applications. The Company is also prospecting new
opportunities in both the complimentary upstream and downstream storage tank
markets.

Titan has taken the necessary progressive steps to position itself within this
new market reality:

/T/

— It has undertaken cost reduction measures that include a significant

reduction in its work force while retaining core engineering, sales and
support teams. The impacts of these cost reduction initiatives are
beginning to be realized in fiscal 2017 and compensation savings of
approximately $1.3 million, as compared to fiscal 2016, are expected.
— It closed its Saskatchewan warehouse and service facility and divested
of its TPZ and 3500 Controller product lines allowing for resources to
be more focused on current and upcoming market opportunities and
products.
— It has completed an intensive review of its R&D program and is now
focused on high potential product development.
— It continues to explore and develop strategic partnerships that will
allow it to expand into new markets.
— It continues to explore new business opportunities to leverage Titan’s
expertise and capital.

/T/

Titan maintains a strong balance sheet that will support strategic initiatives
going forward.

Change of Directors

Titan Logix Corp. announces the appointment of Mr. Alvin Pyke as a director of
the company effective April 12, 2017. Mr. Pyke is President, CEO and founder of
Helical Pier Systems Ltd. Helical Pier Systems Ltd provides design,
manufacturing and installation services across the North American landscape to
the oil and gas industry, electrical power transmission and distribution
companies, and commercial projects. Mr. Pyke is a professional engineer and
entrepreneur with over 30 years of corporate experience.

“I welcome Alvin and the expertise he brings to our Board,” said Grant Reeves,
Chairman. “His experience with technology along with his extensive leadership
experience is an excellent complement to our existing Board.”

In addition, the Company announces the resignation of Charles Buehler from the
board of directors effective April 12, 2017. Mr. Buehler served as a Director
since June 2015, was Chairman of the Board from December 2015 until January
2017, and played an invaluable role on the Board providing guidance through his
experience with public boards and corporate governance along with his extensive
business acumen.

Grant Reeves, Chairman stated, “On behalf of our Company and Directors, I would
like to sincerely thank Charles for his many contributions to Titan. All of us
at Titan Logix wish Mr. Buehler all the best in the future.”

About Titan Logix Corp.:

Founded in 1979, Titan Logix Corp. (“Titan” or “the Company”) is a developer,
manufacturer and marketer of innovative fluid measurement and management
solutions. The Company’s products include Guided Wave Radar (GWR) gauges for
level measurement and overfill prevention (particularly for use in mobile
tanker applications), level gauges for storage tanks, and communication systems
for remote alarming and control. Titan’s products are currently used in the oil
and gas, waste fluid collection, chemical and aviation industries.

Titan’s products are part of a complete asset management solution. The full
solution consists of Titan’s products integrated with best-in-class third party
solutions to enable our complete fluid management throughout each stage of
their fluid handling processes. This is captured by our slogan “Advanced
Technology Fluid Management Solutions, In the Field, On the Road, In the
Office” (TM).

/T/

— In the Field: “In the Field” refers to Titan’s solution offerings for

storage tanks and process vessels.
— On the Road: “On the Road” refers to Titan’s solution offerings for
mobile tanker trucks and trailers.
— In the Office: “In the Office” refers to Titan’s solution offerings that
enable customers to monitor their fluid assets remotely from the
convenience of their dispatch center or other back office environment
through a wired or wireless connection.

/T/

Titan Logix Corp. is a public company listed on the TSX Venture Exchange and
its shares trade under the symbol TLA.

Information in this press release that is not current or historical factual
information may constitute forward looking information within the meaning of
securities laws. Implicit in this information are assumptions regarding our
future operational results. These assumptions, although considered reasonable
by the company at the time of preparation, may prove to be incorrect. Readers
are cautioned that actual performance of the company is subject to a number of
risks and uncertainties and could differ materially from what is currently
expected as set out above. For more exhaustive information on these risks and
uncertainties you should refer to our Management Discussion and Analysis in
respect of the year ended August 31, 2016 which is available at www.sedar.com.
Forward-looking information contained in this press release is based on our
current estimates, expectations and projections, which we believe are
reasonable as of the current date. You should not place undue importance on
forward-looking information and should not rely upon this information as of any
other date. While we may elect to, we are under no obligation and do not
undertake to update this information at any particular time, whether as a
result of new information, future events or otherwise, except as required by
applicable securities law.

– END RELEASE – 13/04/2017

For further information:
Titan Logix Corp.
Douglas Carruthers
Chief Executive Officer
(780) 462-4085
invest@titanlogix.com
www.titanlogix.com

COMPANY:
FOR: TITAN LOGIX CORP.
TSX VENTURE SYMBOL: TLA

INDUSTRY: Computers and Software – Software, Energy and Utilities –
Equipment, Manufacturing and Production – Machinery and Tools
RELEASE ID: 20170413CC0075

Press Release from Marketwired 1-866-736-3779

Westcore Energy Ltd. to Expand Non-Brokered Private Placement and Extend Closing

April 13, 2017 by The Canadian Press

FOR: WESTCORE ENERGY LTD.TSX VENTURE SYMBOL: WTRDate issue: April 13, 2017Time in: 5:45 PM eAttention:
SASKATOON, SASKATCHEWAN–(Marketwired – April 13, 2017) – Westcore Energy Ltd.
(“Westcore” or the “Company”) (TSX VENTURE:WTR) announces that it is e…

Chevron said to be considering sale of stake in Shell oilsands mining project

April 13, 2017 by The Canadian Press

CALGARY — California-based Chevron Corp. is looking at selling its 20 per cent stake in the Athabasca Oil Sands Project in northern Alberta, according to a media report.

The company has discussed with investment banks the idea of selling its stake in the oilsands mine and upgrading project, Reuters is reporting, citing anonymous sources.

Neither Chevron nor project operator Royal Dutch Shell responded immediately to a request for comment on the report.

Last month, Shell announced it had agreed to sell most of its Canadian oilsands assets to Canadian Natural Resources (TSX:CNQ) for C$11.1 billion, comprised of about US$5.4 billion in cash plus 98 million shares.

The two companies also announced they would buy out Houston-based Marathon Oil’s 20 per cent stake in the Athabasca Oil Sands Project for a total of US$2.5 billion.

The deals, which are part of a recent trend by international companies to pull back from the oilsands, are expected to close in mid-2017.

The Canadian Press

Enerflex to Announce First Quarter 2017 Results on May 4, 2017

April 13, 2017 by The Canadian Press

FOR: ENERFLEX LTD.
TSX SYMBOL: EFX

Date issue: April 13, 2017
Time in: 5:20 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 13, 2017) – Enerflex Ltd. (TSX:EFX)
(“Enerflex” or the “Company”), a leading supplier of products and services to
the global energy industry, will release its first quarter 2017 financial
results on May 4, 2017. These results will be available on the Enerflex website
at www.enerflex.com.

Analysts, investors, members of the media, and other interested parties are
invited to participate in a teleconference and audio webcast on Friday, May 5,
2017 at 8:00 a.m. MST to discuss the first quarter 2017 financial results and
operating highlights.

To participate, please call toll free 1.844.231.9067 or 1.703.639.1277. Please
dial in 10 minutes prior to the start of the call. No passcode is required. The
live audio webcast of the teleconference will be available on the Enerflex
website at www.enerflex.com under the Investors section on May 5, 2017 at 8:00
a.m. MST.

The conference will begin with an operations review by J. Blair Goertzen,
President and Chief Executive Officer, as well as a review of the financial
results by D. James Harbilas, Executive Vice President and Chief Financial
Officer, followed by a question and answer period.

A replay of the teleconference will be available on May 5, 2017 at 11:00 p.m.
MST until 11:00 p.m. MST on May 12, 2017. Please call 1.855.859.2056 or
1.404.537.3406 and enter conference ID 8198110.

About Enerflex

Enerflex is a single source supplier of natural gas compression, oil and gas
processing, refrigeration systems, and electric power equipment with in-house
engineering and mechanical service expertise. The Company’s broad in-house
resources provide the capability to engineer, design, manufacture, construct,
commission, and service hydrocarbon handling systems. Enerflex’s expertise
encompasses field production facilities, compression and natural gas processing
plants, C02 processing plants, refrigeration systems, and electric power
equipment servicing the natural gas production industry.

Headquartered in Calgary, Canada, Enerflex has approximately 1,800 employees
worldwide. Enerflex, its subsidiaries, interests in associates and
joint-ventures operate in Canada, the United States, Argentina, Brazil,
Bolivia, Colombia, Mexico, Peru, Australia, the United Kingdom, the United Arab
Emirates, Oman, Bahrain, Indonesia, Malaysia, and Thailand. Enerflex’s shares
trade on the Toronto Stock Exchange under the symbol “EFX”. For more
information about Enerflex, go to www.enerflex.com.

– END RELEASE – 13/04/2017

For further information:
For investor and media inquiries, please contact:
Enerflex Ltd.
J. Blair Goertzen
President & Chief Executive Officer
403.236.6852
OR
Enerflex Ltd.
D. James Harbilas
Executive Vice President & Chief Financial Officer
403.236.6857
www.enerflex.com

COMPANY:
FOR: ENERFLEX LTD.
TSX SYMBOL: EFX

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170413CC0073

Press Release from Marketwired 1-866-736-3779

Ex-exec: paid millions in bribes to Brazil president’s party

April 13, 2017 by The Canadian Press

SAO PAULO — Brazilian construction giant Odebrecht paid $40 million to President Michel Temer’s party and another party to ensure a contract with the state oil company, according to testimony from a former Odebrecht executive.

Marcio Faria’s accusation came in plea bargain testimony released late Wednesday as part of the biggest corruption probe in Brazil’s history. The investigation, known as Operation Car Wash, has already unveiled billions of dollars in kickbacks and bribes paid to politicians by Brazilian companies.

But this week, the Supreme Court announced a new wave of investigations into top politicians, including eight of Temer’s Cabinet ministers, dealing a major blow to his presidency and raising questions about whether he can continue to effectively govern. In opening the investigations, the court released recordings of the plea bargain testimony that underpins the probe.

Other former Odebrecht executives testified that Temer was involved in the solicitation of another bribe, worth $3.2 million.

Temer is not under investigation since, as president, he has temporary immunity from any crimes committed before he took office. He has denied wrongdoing.

In his testimony, Faria said he met with Temer and some of his allies at Temer’s office in Sao Paulo in 2010 in order to “bless” an arrangement whereby Odebrecht would make a contribution to the Brazilian Democratic Movement Party in exchange for its help smoothing the approval of a pending contract with Petrobras.

When asked whether it was clear that this money was a bribe or an illegal gain, Faria responded: “Totally an illegal gain because it was a percentage on top of the contract.”

Faria said no figures were discussed at the meeting, but the deal was clear: Odebrecht would pay the party 5 per cent of the value of the Petrobras contract. That amounted to around $40 million, he said.

Faria said Temer’s party later decided to cut in the Workers’ Party. At the time, Temer was the vice-presidential candidate on a ticket with Dilma Rousseff of the Workers’ Party as the presidential candidate. In the end, Faria said Temer’s party received 4 per cent of the contract’s total, and the Workers’ Party received 1 per cent.

Temer’s office acknowledged that the president had a brief conversation with Faria in 2010, but flatly denied the rest.

“The narrative released today doesn’t correspond to the facts and is based on an absolute lie,” his office said in a statement.

Two other former Odebrecht executives described a similar scenario they say occurred in 2014. According to court documents, the executives had dinner that year with Temer, who was then vice-president, and his current Chief of Staff Eliseu Padilha.

During the dinner, they say, the company agreed to pay $3.2 million in supposed campaign contributions to Padilha and another Temer ally and in exchange, Temer’s party agreed to help Odebrecht win airport concessions. Padilha is under investigation in this case.

Former Odebrecht CEO Marcelo Odebrecht, one of the executives present, testified that he closed the deal with Padilha after dessert and before coffee was served. Temer had stepped away from the table at the time.

“Temer never mentioned the 10 million (reals, or $3.2 million) to me,” Odebrecht said in the recording released by the court. “But obviously at the dinner he was aware.”

Padilha has denied wrongdoing. Temer’s office said that he “categorically denies any involvement of his name in shady dealings.”

The corruption unmasked by the Car Wash investigation has shocked even the most cynical Brazilians for both the vast amounts that traded hands and the way in which it has spared no party. Odebrecht testified that his company also contributed to the presidential campaigns of Rousseff and Luiz Inacio Lula da Silva, both of the Workers’ Party, in exchange for favours.

In one instance, in 2009, Odebrecht met with Silva’s finance minister, Guido Mantega, to discuss an executive order the company wanted from the government. During the conversation, Mantega allegedly wrote down the number 50 — which Odebrecht said he understood meant the company should contribute 50 million reals ($16 million) to Rousseff’s upcoming campaign.

“On illegal campaign financing, Lula and Dilma knew the amounts,” the former CEO testified. “Not the precise amount, but they had knowledge of the dimension of all our support through the years.”

Silva and Rousseff have both denied the accusations. Rousseff was impeached and removed from office last year on charges she broke fiscal laws.

“I don’t know what will happen to me, but I am fighting and I will prove that this country can be happy again,” Silva said in a radio interview on Thursday.

___

Savarese reported from Rio de Janeiro.

Sarah Dilorenzo And Mauricio Savarese, The Associated Press

Anterra Announces Extension of CCAA Protection Until June 2, 2017

April 13, 2017 by The Canadian Press

FOR: ANTERRA ENERGY INC.TSX VENTURE SYMBOL: AE.ADate issue: April 13, 2017Time in: 4:42 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 13, 2017) – Anterra Energy Inc.
(“Anterra” or the “Company”) (TSX VENTURE:AE.A) announces that the Court of
Qu…

Peyto Exploration & Development Corp. Confirms Dividends for Second Quarter 2017

April 13, 2017 by The Canadian Press

FOR: PEYTO EXPLORATION & DEVELOPMENT CORP.
TSX SYMBOL: PEY

Date issue: April 13, 2017
Time in: 4:30 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 13, 2017) – Peyto Exploration &
Development Corp. (“Peyto”) (TSX:PEY) declares the following dividends, payable
to shareholders of its common shares at the close of business on the record
dates indicated.

/T/

Dividend Amount per Record Date Ex-Dividend Date Payment Date
Common Share
—————————————————————————-
$0.11 April 30, 2017 April 26, 2017 May 15, 2017
$0.11 May 31, 2017 May 29 2017 June 15, 2017(i)
$0.11 June 30, 2017 June 28, 2017 July 14, 2017 (i)
—————————————————————————-
(i) Dividends are at the discretion of the Board of Directors and subject
to change.

/T/

Dividends paid by Peyto to Canadian residents are eligible dividends for
Canadian income tax purposes.

Shareholders and interested investors are encouraged to visit the Peyto website
at www.peyto.com to learn more about what makes Peyto one of North America’s
most exciting energy companies. The website also includes the President’s
monthly report, which discusses various topics chosen by the President and
includes estimates of monthly capital expenditures and production. For further
information please contact:

Certain information set forth in this document, including management’s
assessment of Peyto’s future plans and operations, contains forward-looking
statements. By their nature, forward-looking statements are subject to numerous
risks and uncertainties, some of which are beyond these parties’ control,
including the impact of general economic conditions, industry conditions,
volatility of commodity prices, currency fluctuations, imprecision of reserve
estimates, environmental risks, competition from other industry participants,
the lack of availability of qualified personnel or management, stock market
volatility and ability to access sufficient capital from internal and external
sources. Readers are cautioned that the assumptions used in the preparation of
such information, although considered reasonable at the time of preparation,
may prove to be imprecise and, as such, undue reliance should not be placed on
forward-looking statements. Peyto’s actual results, performance or achievement
could differ materially from those expressed in, or implied by, these
forward-looking statements and, accordingly, no assurance can be given that any
of the events anticipated by the forward-looking statements will transpire or
occur, or if any of them do so, what benefits that Peyto will derive therefrom.
The Toronto Stock Exchange has neither approved nor disapproved the information
contained herein.

– END RELEASE – 13/04/2017

For further information:
Peyto Exploration & Development Corp.
Darren Gee
President and Chief Executive Officer
(403) 237-8911
(403) 451-4100 (FAX)

COMPANY:
FOR: PEYTO EXPLORATION & DEVELOPMENT CORP.
TSX SYMBOL: PEY

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170413CC0065

Press Release from Marketwired 1-866-736-3779

Freehold Royalties Ltd. Declares Dividend for April 2017

April 13, 2017 by The Canadian Press

FOR: FREEHOLD ROYALTIES LTD.TSX SYMBOL: FRUDate issue: April 13, 2017Time in: 4:30 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 13, 2017) – Freehold Royalties Ltd.
(Freehold) (TSX:FRU) announces that its Board of Directors has declared a
divid…

Canadian Energy Services & Technology Corp. Announces Cash Dividend and Provides Q1 Conference Call Details

April 13, 2017 by The Canadian Press

FOR: CANADIAN ENERGY SERVICES & TECHNOLOGY CORP.
TSX SYMBOL: CEU
OTCQX SYMBOL: CESDF

Date issue: April 13, 2017
Time in: 4:05 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 13, 2017) – Canadian Energy Services &
Technology Corp. (“CES” or the “Corporation”) (TSX:CEU)(OTCQX:CESDF) announced
today that it will pay a cash dividend of $0.0025 per common share on May 15,
2017, to the shareholders of record at the close of business on April 28, 2017.

CES also announced today that it will conduct its Q1 2017 conference call on
May 12, 2017 following the upcoming release of its financial results for the
first quarter ended March 31, 2017. The Q1 2017 results are expected to be
released after the close of market the day before the conference call. Tom
Simons, President and Chief Executive Officer of CES, will host the call.

/T/

Date: May 12, 2017
Time: 9:00 a.m. MT
Dial-in: (877) 291-4570 or (647) 788-4922
Online: http://www.gowebcasting.com/8431

/T/

A replay of the conference call will be accessible on the Corporation’s
Investor Relations website at www.CanadianEnergyServices.com by selecting “News
Releases”.

About Canadian Energy Services & Technology Corp.

CES is a leading provider of technically advanced consumable chemical solutions
throughout the lifecycle of the oilfield. This includes solutions at the
drill-bit, at the point of completion and stimulation, at the wellhead and
pump-jack, and finally through to the pipeline and midstream market. The
Corporation’s business model is relatively asset light and requires limited
re-investment capital to grow. As a result, CES has been able to capitalize on
the growing market demand for drilling fluids and production and specialty
chemicals in North America while generating free cash flow.

Additional information about CES is available at www.sedar.com or on the
Corporation’s website at www.CanadianEnergyServices.com.

THE TORONTO STOCK EXCHANGE HAS NOT REVIEWED AND DOES NOT ACCEPT RESPONSIBILITY
FOR THE ADEQUACY OR ACCURACY OF THIS RELEASE.

– END RELEASE – 13/04/2017

For further information:
Tom Simons
President and Chief Executive Officer
Canadian Energy Services & Technology Corp.
403-269-2800
OR
Craig Nieboer, CA
Chief Financial Officer
Canadian Energy Services & Technology Corp.
403-269-2800
Or by email at: cesinfo@ceslp.ca

COMPANY:
FOR: CANADIAN ENERGY SERVICES & TECHNOLOGY CORP.
TSX SYMBOL: CEU
OTCQX SYMBOL: CESDF

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170413CC0060

Press Release from Marketwired 1-866-736-3779

PrairieSky Royalty Declares April Dividend and Announces Conference Call for Q1 2017 Results

April 13, 2017 by The Canadian Press

FOR: PRAIRIESKY ROYALTY LTD.TSX SYMBOL: PSKDate issue: April 13, 2017Time in: 4:01 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 13, 2017) – PrairieSky Royalty Ltd.
(“PrairieSky”) (TSX:PSK) announced today that its Board of Directors has
declar…

Tesla Announces Date for First Quarter 2017 Financial Results and Webcast

April 13, 2017 by The Canadian Press

FOR: TESLA, INC.NASDAQ SYMBOL: TSLADate issue: April 13, 2017Time in: 1:43 PM eAttention:
PALO ALTO, CA–(Marketwired – April 13, 2017) – Tesla (NASDAQ: TSLA) will post
its financial results for the first quarter of 2017 after market close on
Wednesday…

Oil demand growth seen slowing for a second year

April 13, 2017 by The Canadian Press

PARIS — The International Energy Agency expects growth in the global demand for crude oil to slow for a second consecutive year in 2017.

The Paris-based agency expects growth of 1.3 million barrels a day this year, compared with 1.4 million barrels previously forecast, due to stalled demand in the U.S., Middle East, Russia and India.

In its monthly report released Thursday, the IEA, a body that advises major oil-consuming nations, says production will grow this year, even when considering pledges by OPEC countries to limit output.

The combination of factors could keep a lid on oil prices, which have risen in the past six months after a three-year slump. On Thursday, the international benchmark for crude oil was up 2 cents at $55.88 a barrel.

The Associated Press

Foremost Income Fund Reviews Unit Redemption Monthly Limit for April 2017

April 13, 2017 by The Canadian Press

FOR: FOREMOST INCOME FUND
Date issue: April 13, 2017Time in: 11:44 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 13, 2017) – Foremost Income Fund
(“Foremost” or the “Fund”) reviews the monthly limit for Unit redemptions
pursuant to section 6.4(…

Trican Well Service Ltd. Announces First Quarter 2017 Conference Call

April 13, 2017 by The Canadian Press

FOR: TRICAN WELL SERVICE LTD.
TSX SYMBOL: TCW

Date issue: April 13, 2017
Time in: 11:03 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 13, 2017) – Trican Well Service Ltd.
(TSX:TCW) (“Trican”) intends to release its First Quarter 2017 results on
Wednesday, May 3, 2017 after the close of the market.

The Company will host a conference call on Thursday, May 4, 2017 at 9:00 a.m.
MT (11:00 a.m. ET) to discuss the Company’s results for the 2017 First Quarter.

To listen to the webcast of the conference call, please enter:
http://edge.media-server.com/m/p/yf32yhja in your web browser or visit the
Investors section of our website at www.tricanwellservice.com/investors and
click on “Reports”.

To participate in the Q&A session, please call the conference call operator at
1-844-358-9180 (North America) or 478-219-0187 (outside North America) 15
minutes prior to the call’s start time and ask for the “Trican Well Service
Ltd. First Quarter 2017 Earnings Results Conference Call”.

The conference call will be archived on Trican’s website at
www.tricanwellservice.com/investors

Headquartered in Calgary, Alberta, Trican provides a comprehensive array of
specialized products, equipment and services that are used during the
exploration and development of oil and gas reserves.

– END RELEASE – 13/04/2017

For further information:
Trican Well Service Ltd.
Dale Dusterhoft
Chief Executive Officer
(403) 266-0202
(403) 237-7716 (FAX)
ddusterhoft@trican.ca
OR
Trican Well Service Ltd.
Michael Baldwin
Senior Vice President, Finance & CFO
(403) 266-0202
(403) 237-7716 (FAX)
mbaldwin@trican.ca
www.tricanwellservice.com

COMPANY:
FOR: TRICAN WELL SERVICE LTD.
TSX SYMBOL: TCW

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170413CC0042

Press Release from Marketwired 1-866-736-3779

OneRoof Energy Announces Settlement of Arbitration Claim Resignation of Chief Executive Officer

April 13, 2017 by The Canadian Press

FOR: ONEROOF ENERGY GROUP, INC.
TSX VENTURE SYMBOL: ON

Date issue: April 13, 2017
Time in: 8:54 AM e

Attention:

SAN DIEGO, CALIFORNIA–(Marketwired – April 13, 2017) – OneRoof Energy, Inc.
(“OneRoof”), a residential solar services provider and wholly-owned subsidiary
of OneRoof Energy Group, Inc. (the “Company”) (TSX VENTURE:ON) announced today
that it has entered into a mutual settlement agreement with Trinity Heating &
Air, Inc., d/b/a Trinity Solar (“Trinity”), settling all claims between the
parties. As previously disclosed on November 11, 2016, Trinity filed an
arbitration action against OneRoof alleging various claims for breach of
contract and common law fraud and seeking over USD$12.5 million in damages. In
response, OneRoof filed various counterclaims against Trinity. The terms of the
settlement included (a) a payment of USD$1,070,000 to Trinity, USD$1 million of
which was being held by a third party in respect of projects previously
developed by Trinity and sold by OneRoof to the third party, and (b) OneRoof’s
transfer of certain solar projects and leads to Trinity.

The Company announced today that its President and CEO, David Field, has
resigned from all positions with the Company and its subsidiaries, including
the board of directors of the Company. Dalton W. Sprinkle, formerly SVP,
General Counsel and Secretary of the Company, has been appointed Interim Chief
Executive Officer, and will continue as General Counsel and Secretary of the
Company as it continues its wind down process.

Caution Regarding Forward-Looking Information

Certain statements contained in this document are “forward-looking information”
within the meaning of applicable securities laws. Forward-looking information
is necessarily based on a certain number of estimates and assumptions, which
while considered plausible by the management when they are made, are inherently
subject to significant commercial, economic and competitive risks and
uncertainties. We advise investors not to rely unduly on forward-looking
information. The Company further declines any intention or obligation to
publicly update this forward-looking information, whether due to new
information, or future or other events, unless required by applicable law.

Neither the TSX Venture Exchange nor its regulation service provider (as these
terms are defined in policies of the TSX Venture Exchange) bears responsibility
for the adequacy or accuracy of this press release.

– END RELEASE – 13/04/2017

For further information:
OneRoof Energy, Inc.
John Bunnel
Interim Chief Financial Officer
(858) 926-7660

COMPANY:
FOR: ONEROOF ENERGY GROUP, INC.
TSX VENTURE SYMBOL: ON

INDUSTRY: Financial Services – Investment Services and Trading
RELEASE ID: 20170413CC0029

Press Release from Marketwired 1-866-736-3779

C-COM Reports First Quarter Results

April 13, 2017 by The Canadian Press

EPA: US Steel leaks chemical into Lake Michigan tributary

April 12, 2017 by The Canadian Press

PORTAGE, Ind. — A spill at a U.S. Steel plant in northern Indiana that sent wastewater containing a potentially carcinogenic chemical into a Lake Michigan tributary was apparently caused by a pipe failure but testing has found none of that toxic substance in the lake, the company and federal officials said Wednesday.

Tuesday’s spill of an unknown amount of wastewater led to the closure of three beach areas at the scenic Indiana Dunes National Lakeshore and prompted a local water utility to stop drawing water from the lake out of “an abundance of caution,” the U.S. Environmental Protection Agency said.

U.S. Steel said a preliminary investigation shows an expansion joint failed Tuesday in a pipe at its Portage, Indiana, facility, allowing wastewater from an electroplating treatment process that contains hexavalent chromium to flow into the wrong wastewater treatment plant at the complex.

That wastewater eventually flowed into the Burns Waterway, a lake tributary, at a point about 100 yards from Lake Michigan, said the EPA, which is overseeing the response to the spill.

Indiana American Water, which operates a water treatment plant at nearby Ogden Dunes that draws water from the lake about two miles from Burns Waterway, temporarily shuttered that plant following the spill, and is instead tapping water reserves.

Andy Maguire, the EPA’s on-scene co-ordinator, said initial water testing results at the utility’s intake point showed hexavalent chromium levels slightly above the detection limit for that chemical. But he said a subsequent test of the same sample showed levels at or below the detection limit, which Maguire called well below EPA’s health-based standard for ingestion of that chemical.

“Even if that number was slightly above the detection limit, it’s below our very conservative health-based levels for ingestion. That’s not a drinking water standard. Those numbers are calculated by an ingestion model,” he said, to account for events such as a person accidentally drinking surface water while swimming.

Maguire said testing is continuing at the intake and other points on the lake and adjacent areas, but hexavalent chromium from the spill has so far not been found in the lake.

The EPA has said that hexavalent chromium — a toxic byproduct of industrial processes — might be carcinogenic if ingested. The toxic heavy metal is used in a variety of industrial processes, including steelmaking and corrosion prevention, and as a pigment in dyes, paints and inks. It’s also found in ash from coal-fired power plants.

A case involving the chemical was made famous by the 2000 film “Erin Brockovich,” which was based on a utility’s disposal of water laced with hexavalent chromium in unlined ponds near Hinkley, California. That disposal method polluted drinking water wells and resulted in a $333 million settlement.

Hexavalent chromium has been linked to a variety of illnesses when inhaled, including lung cancer. Laboratory rats have developed cancer after drinking water tainted with the chemical, according to the National Institutes of Health.

U.S. Steel said the spilled wastewater came from a process used to treat steel after it has been electroplated. That wastewater is supposed to flow into a special treatment plant, but the pipe failure prevented that from happening.

Maguire said EPA and U.S. Steel are still working to determine how much wastewater was discharged.

U.S. Steel has halted all production processes at its Portage facility as it works with the EPA, state and local officials to respond to the spill, repair the damaged pipe and remove the hexavalent chromium.

The National Park Service said it closed three beaches along the nearby Indiana Dunes National Lakeshore. based on a recommendation that all beaches within three miles of the spill site be closed as a precaution to protect park visitors.

The Associated Press

Completion of Placing of New Shares Under General Mandate

April 12, 2017 by The Canadian Press

FOR: SUNSHINE OILSANDS LTD.HKSE SYMBOL: 2012Date issue: April 13, 2017Time in: 12:46 AM eAttention:
HONG KONG, CHINA and CALGARY, ALBERTA–(Marketwired – April 13, 2017) – The
Board of Directors (the “Board”) of Sunshine Oilsands Ltd. (the “Corporation…

National Energy Board expands safety advisory on pipeline materials

April 12, 2017 by The Canadian Press

CALGARY — The National Energy Board is expanding a safety advisory and draft order on unreliable pipeline fittings after learning of more suppliers with quality issues.

The draft order requires companies to verify whether they have any components not meeting specifications, and to file a timeline and plan to address any issues within 60 days.

The regulator says it also plans to hold a technical workshop in June on quality assurance for the pipeline components as the number of cases rise.

The latest advisory by the NEB names South Korea-based TK Corp. and India-based Tecnoforge as having in some cases supplied fittings that didn’t meet material requirements, after identifying Canadoil Asia and Ezeflow Fitting in an advisory issued in February 2016.

The issue with TK Corp. was originally identified by a provincially-regulated operator in 2012, but the Tecnoforge flaws were only discovered last August by a pipeline company before installing the part.

Further investigation found the Tecnoforge fitting had been over-tempered and was weakened in some areas, and that the cause of the problem could happen with other manufacturers as well.

The NEB says there haven’t been any incidents on federally-regulated pipelines because of the problem, but it is taking preventative steps to reduce the potential of future incidents.

The Canadian Press

Pine Cliff Energy Ltd. Announces Borrowing Base Redetermination

April 12, 2017 by The Canadian Press

FOR: PINE CLIFF ENERGY LTD.TSX SYMBOL: PNEDate issue: April 12, 2017Time in: 8:14 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 12, 2017) – Pine Cliff Energy Ltd.
(“Pine Cliff” or the “Company”) (TSX:PNE) is pleased to announce that it has
comp…

Gas prices on the rise, hit highest level in Eastern Canada since late 2014

April 12, 2017 by The Canadian Press

MONTREAL — Drivers facing sticker shock from rising gas prices in many parts of Canada should expect to dig even deeper into their wallets as the summer approaches, says a leading expert on gas prices.

The average price for regular unleaded in the country was about $1.15 per litre as of Wednesday afternoon, according to gas price tracking firm GasBuddy. That’s up almost five cents a litre in one day and 20 per cent from a year ago.

“The numbers are eye-popping but they’re also a source of public angst,” said Dan McTeague, a senior petroleum analyst with GasBuddy.

The combination of higher ingredient costs for summer fuel, growing U.S. demand and the lower value of the loonie have caused prices in Eastern Canada to hit their highest level since October 2014, he said.

The seasonal switch from winter fuel involves the replacement of butane with more expensive alkylates in blended summer gasoline. The growing use of premium fuels for new cars requiring turbo-charged power is also a factor, McTeague added.

Pump prices in the Greater Toronto Area hovered around $1.16, while in Montreal they were $1.25, according to GasBuddy’s website. The highest average gas prices in Canada, aside from the Far North, were in Vancouver at $1.39, and the lowest were in Stonewall, Man., north of Winnipeg, at 99.5 cents.

McTeague said he sees prices rising another three to five cents per litre in Eastern Canada.

“They may stabilize a little bit throughout April and beyond geopolitical considerations, I sense that we are going to be seeing even higher prices throughout the summer, likely due to U.S. demand, which continues to exceed expectations,” he said.

More Americans hitting the road could also mean a third consecutive year of record fuel demand, which will translate into higher pump prices in Canada, he added.

Ross Marowits, The Canadian Press

Dakota Access company can keep some pipeline secrets

April 12, 2017 by The Canadian Press

BISMARCK, N.D. — A federal judge is allowing the developer of the Dakota Access oil pipeline to keep secret some but not all pipeline information that the company believes could be useful to vandals and terrorists.

U.S. District Judge James Boasberg said in a ruling dated Friday that information such as spill risks at various points along the pipeline should be shielded from public view but that certain details relating to how a spill might be handled don’t warrant such protection.

Two American Indian tribes who oppose the pipeline had argued that the spill risk data could bolster their case that more environmental study is needed. Attorneys for the Standing Rock and Cheyenne River Sioux didn’t immediately respond to requests for comment Wednesday.

Vicki Granado, a spokeswoman for pipeline developer Energy Transfer Partners, declined to comment, citing the tribes’ ongoing federal lawsuit over the $3.8 billion project to move North Dakota oil to a distribution point 1,200 miles away in Illinois.

The Texas-based developer in February asked Boasberg to shield information that it contends could be used by anyone “with the malicious intent to damage the pipeline.” At the time, there had been about 750 arrests of anti-pipeline activists in North Dakota since August, and also vandalism to company equipment in Iowa and North Dakota during construction. In March, there were confirmed instances in which someone apparently had used a torch to burn holes through empty sections of the pipeline at aboveground shut-off valve sites, though no one was arrested.

Attorneys for the tribes, which are suing because they believe the pipeline threatens water, sacred sites and their religion, objected to the company’s request to keep documents secret. They called the company’s reasoning “a ruse” to conceal documents that undermine its assertion that no further environmental review of the pipeline is needed because it’s safe.

The Army Corps of Engineers, which also is a defendant in the lawsuit because it permitted pipeline water crossings, maintained that only a limited amount of the information should be kept from public view based on analyses by the Transportation Security Administration and the Pipeline and Hazardous Materials Safety Administration.

Boasberg reviewed those agencies’ determinations before reaching his decision. The judge is allowing the shielding of documents that include such details as pipeline maps at certain crossings, information on detecting and shutting down spills, graphs of spill risk scores at various points along the pipeline, maps of spill scenarios, oil spill volume predictions and details related to monitoring systems.

Boasberg said “the asserted interest in limiting intentionally inflicted harm outweighs the tribes’ generalized interests in public disclosure and scrutiny,” noting that tribal attorneys would be privy to the information anyway as their lawsuit proceeds. Standing Rock attorney Jan Hasselman has argued previously that public scrutiny of the documents could help the tribe.

Among the information that the judge won’t allow to be kept from the public are the phone numbers of government agencies, the names of waterways that could be affected by spills, and maps and descriptions of oil spill handling methods.

___

Follow Blake Nicholson on Twitter at https://twitter.com/ NicholsonBlake

Blake Nicholson, The Associated Press

Significant Progress Achieved at Serowe Project

April 12, 2017 by The Canadian Press

FOR: STRATA-X ENERGY LTD.TSX VENTURE Symbol: SXEASX Symbol: SXADate issue: April 12, 2017Time in: 6:30 PM eAttention:
DENVER, CO and BRISBANE, AUSTRALIA and VANCOUVER, BC –(Marketwired – April
12, 2017) –
HIGHLIGHTS
/T/
— Strata-X is currently revie…

Lac-Megantic criminal negligence trial in September to be bilingual

April 12, 2017 by The Canadian Press

SHERBROOKE, Que. — The trial later this year for three ex-railway employees charged criminally in the Lac-Megantic train disaster will be heard by a bilingual jury in another town.

A spokesman for the Crown says Quebec Superior Court Justice Gaetan Dumas ruled on the venue and language on Monday as lawyers argue several motions on the case this week.

The July 2013 disaster killed 47 people in the small Quebec town and forced thousands from their homes as fire from a derailed train engulfed and destroyed most of the downtown core.

Three ex-railway employees — train driver Thomas Harding, railway traffic controller Richard Labrie and Jean Demaitre, the manager of train operations — have pleaded not guilty to 47 counts of criminal negligence causing death.

Their bilingual trial is to be held in Sherbrooke instead of Lac-Megantic and is set to last from Sept. 11 to Dec. 21.

Conviction on a charge of criminal negligence causing death carries a maximum penalty of life in prison.

The bankrupt former railway company, Montreal Maine and Atlantic Railway, was charged with the three men and has pleaded not guilty to similar charges.

It will face a separate trial at a later date.

The Canadian Press

Point Loma Resources Files Amended Material Change Report

April 12, 2017 by The Canadian Press

FOR: POINT LOMA RESOURCES LTDTSX VENTURE Symbol: PLXDate issue: April 12, 2017Time in: 5:00 PM eAttention:
CALGARY, AB –(Marketwired – April 12, 2017) – Point Loma Resources Ltd. (TSX
VENTURE: PLX) (the “Corporation” or “Point Loma”) announces that i…

EPCOR to oversee Edmonton’s entire water utility cycle

April 12, 2017 by The Canadian Press

FOR: EPCOR UTILITIES INC.

Date issue: April 12, 2017
Time in: 5:00 PM e

Attention:

EDMONTON, ALBERTA–(Marketwired – April 12, 2017) – Edmonton City Council today
approved transfer of its Drainage utility to EPCOR Utilities Inc.

“We believe Council has made a thoughtful, forward-looking decision following a
thorough and transparent review process,” said EPCOR President & CEO Stuart
Lee. “As confirmed by an independent assessment, this transfer will result in
clear benefits to the City and its citizens.”

EPCOR is 100% owned by the City of Edmonton. Following the transfer, City
Council will continue to regulate Drainage customer rates and be engaged in the
utility’s long-term planning.

Once the transfer is complete, EPCOR will oversee the City’s entire water
utility cycle, which includes drinking water treatment, water distribution,
wastewater treatment and now, wastewater and stormwater collection.

EPCOR anticipates that finalization of the terms of the Drainage transfer,
including completion of a franchise agreement, and the transfer of the assets
is expected to occur on September 1, 2017. In connection with the transfer,
EPCOR will become responsible for future capital costs and assume
responsibility for approximately $600 million to $650 million in current
drainage-related City debt.

“Our focus will now be on the smooth transition of Drainage operations to
EPCOR. We look forward to welcoming Drainage employees and ensuring customers
continue to receive excellent service,” said Lee.

Forward Looking Information

Certain statements and other information included in this media release
constitute “forward-looking information”, “financial outlook” or
“forward-looking statements” (collectively, “FLS”), including, but not limited
to, statements regarding anticipated completion and timing of the transfer of
the Drainage assets and related terms including the assumption of debt. The
purpose of this information is only to provide readers with an indication of
the expected impact of the proposed transaction on EPCOR’s future financial
results and this information may not be appropriate for other purposes. These
statements speak only as of the date of this media release and EPCOR does not
undertake any obligation to publicly update or revise any FLS. Any FLS
contained herein are expressly qualified by this cautionary statement.

About EPCOR Utilities Inc.

EPCOR’s wholly-owned subsidiaries build, own and operate electrical
transmission and distribution networks, water and wastewater treatment
facilities and infrastructure in Canada and the United States. The company’s
subsidiaries also provide electricity and water services and products to
residential and commercial customers. EPCOR, headquartered in Edmonton,
Alberta, is an Alberta Top 70 employer. EPCOR’s website is www.epcor.com.

– END RELEASE – 12/04/2017

For further information:
EPCOR Utilities Inc.
Tim le Riche
External Communications Specialist
780-969-8238 or Cell 780-721-2013
tleriche@epcor.com
www.epcor.com

COMPANY:
FOR: EPCOR UTILITIES INC.

INDUSTRY: Energy and Utilities – Utilities, Energy and Utilities –
Pipelines
RELEASE ID: 20170412CC0106

Press Release from Marketwired 1-866-736-3779

What retrofits 400 horsepower motors, saves lots of electricity and is like taking 325 homes off Alectra’s grid in Bradford?

April 12, 2017 by The Canadian Press

FOR: ALECTRA INC.

Date issue: April 12, 2017
Time in: 2:37 PM e

Attention:

Bradford chemical manufacturer receives cheque for $82,711 for energy
efficient retrofits

BRADFORD, ON –(Marketwired – April 12, 2017) – Galata Chemicals, one of the
world’s leading producers and marketers of additives for the Polyvinyl
Chloride (PVC) and associated industries, was recognized Wednesday by Alectra
Utilities (formerly PowerStream) for reducing its electricity consumption by
28 per cent through its participation in the utility’s Save on Energy RETROFIT
program.

Galata Chemicals (formerly Solucor), an international manufacturer with a
plant in Bradford, Ontario, was presented with a cheque in the amount of
$82,711 as a result of its involvement in the program.

The company has participated in several retrofit projects over the years,
including one involving lighting, but has recently completed the conversion of
key pieces of equipment to Variable Frequency Drives (VFDs). What made the
projects unique was the sheer size of the motors being controlled, some of
which are 400 horsepower.

The conversion to VFDs will reduce the company’s electricity consumption by
2,859,942 kilowatt-hours per year, the equivalent of removing 325 homes off
the grid. It will result in electricity savings for Galata Chemicals of over
$400,000 per year.

VFDs are becoming more widely used in all sorts of applications. They are
capable of varying the output speed of a motor without the need for mechanical
pulleys, which reduces the number of mechanical components and overall
maintenance. The biggest advantage that a VFD has is the ability to save money
for the customer by consuming only the electricity needed for the work
required at the time. Since electricity is a controllable operating expense,
any energy reductions achieved will result in almost immediate, corresponding
reductions in operating costs.

“Galata Chemicals has demonstrated a proactive approach to managing their
energy costs and it is their strength and leadership that serves as an example
to others to pursue similar objectives,” said Mark Henderson, SVP, Energy
Solutions & Services for Alectra. “As Canada’s largest municipally-owned
electricity distribution company based on the total number of customers
served, our team of experts has the expertise to help customers like Galata
Chemicals navigate the retrofit process and realize the incentives available
through the Save on Energy RETROFIT program.”

About Alectra’s Family of Companies

Alectra’s family of energy companies distributes electricity to nearly one
million customers in Ontario’s Greater Golden Horseshoe Area and provides
innovative energy solutions to these and thousands more across Ontario. Our
employees are allies in helping customers discover the possibilities of energy
conservation and new technologies for enhancing their quality of life.

Image Available: http://www.marketwire.com/library/MwGo/2017/4/12/11G135772/Images/Galata-040e03b7cea1a104bd2dc3271fd3d1f1.JPG

– END RELEASE – 12/04/2017

For further information:

Eric Fagen
Email – media@alectra.com
Media Phone Line – 1-844-372-4400

COMPANY:
FOR: ALECTRA INC.

INDUSTRY: Automotive – Cars, Chemicals – Wholesalers and Distributors, Energy
and Utilities – Pipelines, Energy and Utilities – Utilities,
Environment – Natural Resource Management, Government – Local

RELEASE ID: 20170412CC012

Press Release from Marketwired 1-866-736-3779

Inter Pipeline Announces $500 Million Medium-Term Note Offering

April 12, 2017 by The Canadian Press

FOR: INTER PIPELINE LTD.
TSX SYMBOL: IPL

Date issue: April 12, 2017
Time in: 2:25 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 12, 2017) –

NOT FOR DISTRIBUTION TO U.S. NEWSWIRE SERVICES OR FOR DISSEMINATION IN THE
UNITED STATES

Inter Pipeline Ltd. (“Inter Pipeline”) (TSX:IPL) announced today that it has
agreed to issue $500 million of senior unsecured medium-term notes in the
Canadian public debt market. The notes will have a fixed interest rate of
2.734% per annum, payable semi-annually, and will mature on April 18, 2024.

The offering is expected to close on April 18, 2017. Inter Pipeline will use
the net proceeds of the offering to repay indebtedness under its revolving
credit facility and for other general corporate purposes.

The notes are being offered through a syndicate of dealers co-led by BMO
Capital Markets, CIBC Capital Markets and TD Securities Inc. under Inter
Pipeline’s short form base shelf prospectus dated December 11, 2015, a related
prospectus supplement dated September 8, 2016 and a pricing supplement to be
dated April 12, 2017.

This news release does not constitute an offer to sell or the solicitation of
an offer to buy the notes in any jurisdiction, in which such an offer,
solicitation or sale would be unlawful. The notes being offered have not been
approved or disapproved by any regulatory authority. The notes have not been
and will not be registered under the United States Securities Act of 1933, as
amended (the “U.S. Securities Act”), or any state securities laws, and may not
be offered, sold or delivered within the United States or to, or for the
account or benefit of, U.S. persons unless an exemption from the registration
requirements of the U.S. Securities Act is available.

Inter Pipeline Ltd.

Inter Pipeline is a major petroleum transportation, natural gas liquids
processing and bulk liquid storage business based in Calgary, Alberta, Canada.
Inter Pipeline owns and operates energy infrastructure assets in western Canada
and Europe. Inter Pipeline is a member of the S&P/TSX 60 Index and its common
shares trade on the Toronto Stock Exchange under the symbol IPL.
www.interpipeline.com

Disclaimer

Certain information contained herein may constitute forward-looking statements
that involve risks and uncertainties. Readers are cautioned not to place undue
reliance on forward-looking statements, including, but not limited to,
statements regarding the anticipated closing date of the offering and the use
of proceeds of the offering. Such information, although considered reasonable
by Inter Pipeline at the time of preparation, may later prove to be incorrect
and actual results may differ materially from those anticipated in the
statements made. For this purpose, any statements that are not statements of
historical fact may be deemed to be forward-looking statements. Forward-looking
statements often contain terms such as “may”, “will”, “should”, “anticipate”,
“expects” and similar expressions. Such risks and uncertainties include, but
are not limited to, risks associated with operations, such as loss of markets,
regulatory matters, environmental risks, industry competition, potential delays
and cost overruns of construction projects, and the ability to access
sufficient debt or equity capital from internal and external sources. You can
find a discussion of those risks and uncertainties in Inter Pipeline’s
securities filings at www.sedar.com. The forward-looking statements contained
in this news release are made as of the date of this document, and, except to
the extent required by applicable securities laws and regulations, Inter
Pipeline assumes no obligation to update or revise forward-looking statements
made herein or otherwise, whether as a result of new information, future
events, or otherwise. The forward-looking statements contained in this document
are expressly qualified by this cautionary note.

All dollar values are expressed in Canadian dollars unless otherwise noted.

– END RELEASE – 12/04/2017

For further information:
Investor Relations:
Jeremy Roberge
Vice President, Capital Markets
403-290-6015 or 1-866-716-7473
investorrelations@interpipeline.com
OR
Media Relations:
Breanne Oliver
Manager Corporate Communications
587-475-1118
mediarelations@interpipeline.com

COMPANY:
FOR: INTER PIPELINE LTD.
TSX SYMBOL: IPL

INDUSTRY: Energy and Utilities – Oil and Gas , Energy and Utilities
– Pipelines
RELEASE ID: 20170412CC0086

Press Release from Marketwired 1-866-736-3779

In Calgary April 25th – “Canada and the Future of the Economic Regions in the Americas Pacific” – Read About Forum, Speakers & Details HERE

June 28, 2017April 12, 2017 by EnergyNow Media

By Miguel Cortines, President Canadian Council for the Americas Alberta April 10, 2017 CCA Alberta has put together an outstanding international business forum with an impressive lineup of guest speakers who will discuss “Canada and the Future of the Economic Regions in the Americas- Pacific”. The Forum format includes keynote addresses and business panels to … Read more

The Permian Basin: Is This the Tail That Wags The World Oil Dog? – David Yager – Yager Management

June 28, 2017April 12, 2017 by EnergyNow Media

David Yager – Yager Management Ltd. Oilfield Service Management Consulting – Oil & Gas Writer – Energy Policy Analyst April 12, 2017 The old saying goes, “Everything’s bigger in Texas”. The latest subject of this axiom is the legendary Permian Basin. The recent headlines have been eye-popping. “The Permian Basin … Read more

Alberta wildfire evacuation highlights growing use of tracking workers using RFID

April 12, 2017 by The Canadian Press

CALGARY — When last year’s ferocious Alberta wildfire threatened Suncor Energy’s oilsands upgrader near Fort McMurray, the rush to safely remove hundreds from the area provided a rare large-scale test of technology that can let companies know the location of every single worker.

The evacuation highlighted how radio-frequency identification (RFID) technology — long used to track products in warehouses, equipment in mines and even cattle in feedlots — is increasingly being used to monitor workers on big Canadian industrial sites.

Everyone at the Suncor (TSX:SU) site last May was wearing an RFID fob, which identifies who and where they were and includes a “panic button” that can be pushed to summon help, said Doreen Cole, the company’s senior vice-president of oilsands maintenance and reliability.

“Over 1,000 workers were confirmed as safely evacuated in about 30 minutes,” she said, adding that most were not Suncor staff but contractors performing maintenance during a planned shutdown.

Safety is not the only reason for their use. Suncor CEO Steve Williams said on a recent conference call that the technology — piloted since the fall of 2015 — had been so beneficial in terms of productivity that the fobs will be expanded to the Syncrude Canada oilsands upgrader during future maintenance shutdowns.

An Illinois-based company called Zebra Technologies has also put the devices in the shoulder pads of NFL players to allow coaches to track their movements on the field. And some cruise lines have installed them in passengers’ wristbands to figure out who is on and off the ship.

Ed Nabrotzky, chief solutions officer for Omni-ID, a Rochester, N.Y., company that makes RFID fobs, said applications that track people at industrial work sites are a small but growing market for RFID devices.

“I know of maybe 20 to 25 companies that are providing this kind of industrial tracking device,” he said. “You might have a $25-million or $30-million global market.”

Suncor’s RFID system was purchased through technology consulting firm Accenture.

Geoff Hill, Accenture’s Calgary office manager, said the personnel tracking systems are attracting a lot of attention in Canada given their many uses. The data they provide can improve efficiency by identifying choke points in worker flows. They also monitor how many contractors are on site and for how long, which can help reconcile billing.

Installing a system requires integrating dozens or hundreds of wireless transponders to gather data and transmit it to a central website for analysis. Hill said for companies to change the way work is done, engaging with staff, their unions and contractors is key.

“When all of that happens, it’s very positive,” he said.

The prospect of an employer tracking a worker’s every move does raise privacy issues. But so far at Suncor, the safety offered by the technology has trumped privacy concerns, said Ken Smith, president of Unifor 707-A. The union represents about 3,450 Suncor workers, including about 500 who regularly wear the trackers.

“‘Big Brother is watching’ is becoming more a part of the workplace,” he said. “But so far they haven’t had one disciplinary hearing where it was indicated those wearing tracking devices were out of the workplace area or wasting time or anything like that.”

A second type of RFID fob is worn by Suncor employees on site when the upgrader is running. It identifies people and has a panic button but also detects harmful gases and raises an alarm if there’s no movement for a period of time, possibly indicating someone is ill or injured.

Suncor says it looks at aggregate data from five or more workers when analyzing its tracking data to avoid invading the privacy of individuals.

Follow @HealingSlowly on Twitter.

Dan Healing, The Canadian Press

When You Need Local Propane Service – Bluewave Energy Provides Superior Customer Value

October 12, 2017April 12, 2017 by EnergyNow Media

When you need propane at a remote job site quickly, safely and reliably, you can count on Bluewave Energy to deliver. When your crew is counting on you, the last thing you want is to reach a call centre where no one can relate to where you are, or what you need, … Read more

New West Energy Services Comments on Market Activity

April 12, 2017 by The Canadian Press

FOR: NEW WEST ENERGY SERVICES INC.
TSX VENTURE SYMBOL: NWE

Date issue: April 12, 2017
Time in: 11:57 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 12, 2017) – New West Energy Services
Inc. (TSX VENTURE:NWE), an oil and gas and environmental services company
focused on Western Canada, today, at the request of the Investment Industry
Regulatory Organization of Canada (IIROC), announced that NWE’s management is
unaware of any material change in the company’s operations that would account
for the recent increase in market activity.

Neither the TSXV nor its Regulation Services Provider (as that term is defined
in the policies of the TSXV) accepts responsibility for the adequacy or
accuracy of this release.

Cautionary Note Regarding Forward-Looking Information

Certain statements in this news release may constitute “forward-looking
information” within the meaning of applicable securities laws that involve
known and unknown risks, uncertainties and other factors that may cause actual
results, performance or achievements or industry results to be materially
different from any future results, performance or achievements or industry
results expressed or implied by such forward-looking information and financial
outlook. Forward-looking information is identified by the use of terms and
phrases such as “anticipate”, “believe”, “could”, “estimate”, “expect”,
“intend”, “may”, “plan”, “predict”, “project”, “will”, “would”, and similar
terms and phrases, including references to assumptions. Such information may
involve, but is not limited to, comments with respect to strategies,
expectations, planned operations or future actions. Forward-looking information
in this news release includes, without limitation, statements with respect to:
the use of proceeds of its loans; the use of the acquired equipment; planned
changes in NWE’s business and revenues; the competitive environment in which
NWE operates; and the assessment of future plans and operations. Actual events
or results may differ materially. The forward-looking information in this news
release is based on assumptions which includes, but is not limited to: NWE
realizing the expected benefits of its loans and acquired equipment; the
general state of the economy and the oil and gas industry not worsening; NWE
not losing any key personnel; NWE sustaining or increasing their level of
revenues and EBITA; NWE growing its businesses long term and managing its
growth; NWE complying with existing regulations and not becoming subject to
more stringent regulations; and, NWE’s insurance being sufficient to cover
losses that may occur as a result of its operations.
The forward-looking information in this news release is subject to risks,
uncertainties and other factors that could cause actual results to differ
materially from historical results or results anticipated by the
forward-looking information. The factors which could cause results to differ
from current expectations include, but are not limited to: failure to realize
the expected benefits of its loans and acquired equipment; potential
undisclosed liens associated with the acquired equipment; NWE’s results being
dependent upon the general state of the economy and the oil and gas industry;
NWE being dependent on key personnel, the loss of which could harm its
business; NWE may not be able to sustain or increase their revenues or EBITA;
NWE may be unable to grow its business long term or to manage any growth; NWE
may be unable to integrate the acquired equipment into its business;
competition in NWE’s markets may lead to reduced revenues and EBITA; NWE may
fail to comply with existing regulations or become subject to more stringent
regulations; NWE’s insurance may be insufficient to cover losses that may occur
as a result of NWE’s operations; the market price of NWE’s common shares will
fluctuate; and, there is a possibility of dilution of existing holders of NWE’s
common shares due to future financings or acquisitions. Although NWE has
attempted to identify factors that would cause actual actions, events or
results to differ materially from those disclosed in the forward-looking
statements in this news release, there may be other factors that cause actions,
events or results not to be as anticipated, estimated or intended. Also, many
of the factors are beyond the control of NWE. Accordingly, readers should not
place undue reliance on the forward-looking information in this news release.
The forward-looking information is made as of the date of this news release,
and NWE does not assume any obligation to publicly update or revise such
forward-looking information to reflect new information, subsequent or
otherwise, except as may be required by applicable law. The forward-looking
information contained herein is expressly qualified in its entirety by this
cautionary statement.

– END RELEASE – 12/04/2017

For further information:
New West Energy Services Inc.
Gerry E. Kerkhoff
President & Chief Executive Officer
403.984.9798 or 1.888.977.2327 (BEAR)
403.984.9799 (FAX)
gkerkhoff@newwestenergyservices.com

COMPANY:
FOR: NEW WEST ENERGY SERVICES INC.
TSX VENTURE SYMBOL: NWE

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170412CC0073

Press Release from Marketwired 1-866-736-3779

DIVERGENT Energy Services Announces update on Linear Electromagnetic Submersible Pump

April 12, 2017 by The Canadian Press

FOR: DIVERGENT ENERGY SERVICES CORP.
TSX VENTURE SYMBOL: DVG

Date issue: April 12, 2017
Time in: 10:56 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 12, 2017) –

NOT FOR DISSEMINATION IN THE UNITED STATES OF AMERICA

DIVERGENT Energy Services Corp. (“Divergent” or “the Corporation”) (TSX
VENTURE:DVG) is pleased to announce that the Linear Electromagnetic Submersible
Pump (the “Linear Pump”) installed into a client oil well in Southeast
Saskatchewan on March 24, 2017 has been pumping continuously since the start of
the test.

This most recent install includes a tool that restricts tubing movement, which
had been identified as the cause of power cable failures. Ken Berg, President &
CEO, states “The results of incorporating a tubing anchor were realized as soon
as we turned on the pump. The slight vibration at the wellhead (from tubing
movement) felt on previous tests has been eliminated. The pump is running
smoothly and I’m optimistic we will achieve a long run time”.

The Corporation continues to pursue additional installations in both Canada and
the United States and continue to move towards commercialization.

The Corporation’s vision is to be a premier supplier of submersible pumping
products that increase production, while reducing costs and carbon footprint.
The commercialization of our Linear Pump represents a build on our existing
electric submersible pump (“ESP”) business, and will provide oil and gas
companies with the opportunity to capitalize on the Linear Pump’s many benefits
while differentiating Divergent within a competitive and growing market.

ABOUT THE PUMP

The Linear Pump eliminates the ongoing cost of rod and tubing wear in oil
wells, which can help oil and gas producers drive down operating costs, enhance
field efficiencies and improve operations. In the current weak commodity price
environment, such cost savings can represent a significant benefit to producers
seeking to maximize netbacks and control operating and capital costs.

The electromagnet motor duplicates the reciprocating motion currently created
by pumpjacks, but does it at the bottom of the well, eliminating the rod
strings and surface lifting equipment typically used in oil wells. The Pump’s
power is generated by a magnetic field that causes the magnetic shaft of the
motor to move in a back and forth, or linear, motion. All moving parts are
contained within the submersible housing, allowing the Pump to be placed lower
in the well than traditional rod pumps. Placing pumps lower in a well typically
maximizes “draw down” and increases production.

ABOUT DIVERGENT ENERGY SERVICES CORP.

Headquartered in Calgary, Alberta, DIVERGENT Energy Services Corp. provides an
array of artificial lift products and services that are used in the oil and gas
industry, including its revolutionary Linear Electric Submersible Pump.
Divergent’s Pump is approaching commercialization and is targeted to replace
traditional oil pumpjacks. Other Divergent products currently in use by its oil
and gas industry customers include Electric Submersible Pumps and Electric
Submersible Progressing Cavity Pumps.

FORWARD LOOKING STATEMENTS

This document contains information that constitutes forward-looking information
and financial outlook within the meaning of applicable securities legislation.
This forward-looking information and financial outlook is identified by the use
of terms and phrases such as “anticipate,” “achieve”, “achievable,” “believe,”
“estimate,” “expect,” “intend”, “plan”, “planned”, and other similar terms and
phrases. This information and outlook speaks only as of the date of this
document and we do not undertake to publicly update the forward-looking
information and financial outlook contained in this document except in
accordance with applicable securities laws.

Forward-looking information and financial outlook is based on current
expectations, estimates, projections and assumptions, which we believe are
reasonable but which may prove to be incorrect and therefore such
forward-looking information and financial outlook should not be unduly relied
upon. In addition to other factors and assumptions which may be identified in
this document, assumptions have been made regarding, among other things:
industry activity; the general stability of the economic and political
environment; effect of market conditions on demand for the Company’s products
and services; the ability to obtain qualified staff, equipment and services in
a timely and cost efficient manner; the ability to operate its business in a
safe, efficient and effective manner; the performance and characteristics of
various business segments; the effect of current plans; the timing and costs of
capital expenditures; future oil and natural gas prices; currency, exchange and
interest rates; the regulatory framework regarding royalties, taxes and
environmental matters in the jurisdictions in which the Company operates; and
the ability of the Company to successfully market its products and services.

– END RELEASE – 12/04/2017

For further information:
Ken Berg
President and Chief Executive Officer
OR
Scott Hamilton
Chief Financial Officer
OR
DIVERGENT Energy Services Corp.
1500, 715 – 5th Ave SW, Calgary, AB T2P 2X6
(403) 543-0060
(403) 543-0069 (FAX)
www.divergentenergyservices.com

COMPANY:
FOR: DIVERGENT ENERGY SERVICES CORP.
TSX VENTURE SYMBOL: DVG

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170412CC0068

Press Release from Marketwired 1-866-736-3779

Valener and Gaz Metro Conference Call to Discuss Second Quarter 2017 Results

April 12, 2017 by The Canadian Press

FOR: VALENER INC.TSX SYMBOL: VNRTSX SYMBOL: VNR.PR.ADate issue: April 12, 2017Time in: 9:47 AM eAttention:
MONTREAL, QUEBEC–(Marketwired – April 12, 2017) – Valener Inc. (“Valener”)
(TSX:VNR)(TSX:VNR.PR.A) and Gaz Metro Limited Partnership (“Gaz Metro…

Just Energy Preferred Shares Added to the S&P U.S. Preferred Share Index

April 12, 2017 by The Canadian Press

FOR: JUST ENERGY GROUP INC.
NYSE SYMBOL: JE
TSX SYMBOL: JE

Date issue: April 12, 2017
Time in: 8:00 AM e

Attention:

TORONTO, ONTARIO–(Marketwired – April 12, 2017) – Just Energy Group, Inc.
(TSX:JE) (NYSE:JE), a leading retail energy provider specializing in
electricity and natural gas commodities, energy efficiency solutions, and
renewable energy options, today announced that Just Energy Cumulative Preferred
Registered Shares Series A (JE PR A) have been added to the S&P U.S. Preferred
Share Index following rebalancing results on April 7th, 2017. The addition of
Just Energy preferred shares will be effective prior to the open of trading on
April 24th, 2017.

The S&P U.S. Preferred Stock Index is designed to serve the investment
community’s need for an investable benchmark representing the U.S. preferred
stock market. The index includes all preferred stocks issued by corporations
and trading on major U.S. exchanges, subject to criteria relating to minimum
size, liquidity and time to maturity.

About Just Energy Group Inc.

Established in 1997, Just Energy is a leading retail energy provider
specializing in electricity and natural gas commodities, energy efficiency
solutions, and renewable energy options. With offices located across the United
States, Canada, the United Kingdom and Germany, Just Energy serves
approximately two million residential and commercial customers providing homes
and businesses with a broad range of energy solutions that deliver comfort,
convenience and control. Just Energy Group Inc. is the parent company of Amigo
Energy, Green Star Energy, Hudson Energy, Just Energy Solar, Tara Energy and
TerraPass. Visit justenergygroup.com to learn more. Also, find us on Facebook
and follow us on Twitter.

FORWARD-LOOKING STATEMENTS

This press release may contain forward-looking statements and information.
Forward-looking statements and information in this press release include, but
are not limited to, the redemption of the Debentures and the timing thereof.
These statements are based on current expectations that involve a number of
risks and uncertainties which could cause actual results to differ from those
anticipated. These risks include, but are not limited to general economic and
market conditions, levels of customer natural gas and electricity consumption,
rates of customer additions and renewals, rates of customer attrition,
fluctuations in natural gas and electricity prices, changes in regulatory
regimes, results of litigation and decisions by regulatory authorities,
competition and dependence on certain suppliers. Additional information on
these and other factors that could affect Just Energy’s operations, financial
results or dividend levels are included in Just Energy’s annual information
form and other reports on file with Canadian securities regulatory authorities
which can be accessed through the SEDAR website at www.sedar.com, on the SEC’s
website at www.sec.gov or through Just Energy’s website at
www.justenergygroup.com.

Neither the Toronto Stock Exchange nor the New York Stock Exchange has approved
nor disapproved of the information contained herein.

– END RELEASE – 12/04/2017

For further information:
Pat McCullough
Chief Financial Officer
Just Energy
713-933-0895
pmccullough@justenergy.com
OR
Michael Cummings
Investor Relations
Alpha IR Group
617-461-1101
michael.cummings@alpha-ir.com

COMPANY:
FOR: JUST ENERGY GROUP INC.
NYSE SYMBOL: JE
TSX SYMBOL: JE

INDUSTRY: Energy and Utilities – Oil and Gas , Financial Services –
Personal Finance
RELEASE ID: 20170412CC0026

Press Release from Marketwired 1-866-736-3779

Canacol Energy Ltd. Provides Guidance for 2017

April 12, 2017 by The Canadian Press

FOR: CANACOL ENERGY LTD.
TSX SYMBOL: CNE
OTCQX SYMBOL: CNNEF
BVC SYMBOL: CNEC

Date issue: April 12, 2017
Time in: 7:00 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 12, 2017) – Canacol Energy Ltd.
(“Canacol” or the “Corporation”) (TSX:CNE)(OTCQX:CNNEF)(BVC:CNEC) is pleased to
provide the following update concerning its corporate guidance for 2017.

The Corporation announces that its 2017 capital budget is US$ 89 million, with
forecast realized contractual oil and gas sales anticipated to average between
18,000 and 19,000 barrels of oil equivalent per day (“boepd”). The Corporation
forecasts realized contractual oil and gas sales of approximately 25,000 boepd
in December 2017 upon completion of the new private pipeline connecting
Canacol’s gas processing facility at Jobo to the Promigas export line to
Cartagena.

Charle Gamba, President and CEO of the Corporation, commented “Management’s
three primary goals for the year include:

/T/

1. Achieve gas production of 130 million standard cubic feet per day

(“MMscfpd”) by December 2017 via the construction of a new private gas
pipeline designed to transport 40 MMscfpd of new gas production;
2. Drill three gas exploration wells to continue to build the Corporation’s
gas reserves base at industry leading F&D costs; and
3. Drill two oil exploration wells to increase oil production and satisfy
exploration commitments to the government of Colombia.

/T/

Our main goal for 2017 is lifting gas production to 130 MMscfpd in December
2017 via our new private gas pipeline connecting the Jobo gas processing
facility to the Promigas pipeline to Cartagena at Bremen. The Corporation’s
existing 13 gas wells and gas processing facility are capable of a production
rate of approximately 200 MMscfpd, more than sufficient to fulfill our December
1, 2017 sales contracts of 130 MMscfpd. Work on the new gas pipeline that will
add 100 MMscfpd by late 2018 commenced in October of 2016, and the Special
Purpose Vehicle that will add 40 MMscfpd by late 2017 has already placed the
order for 82 kilometers of pipe, and is completing purchase of the right of way
for the pipeline. Excavation and installation of the pipeline is anticipated to
commence in September 2017, with completion by November 2017 and first gas on
December 1, 2017.

With respect to management’s goal of drilling three gas exploration wells in
2017, the Corporation spud the Canahuate 1 exploration well in March 2017 and
plans to drill two additional gas exploration wells, Toronga 1 and Pandereta 1,
in June and September of 2017, respectively. These three wells are targeting
new reserves and production to allow the Corporation to achieve its production
target of 230 MMscfpd in December 2018 when Promigas completes its second
expansion of the Jobo – Cartagena – Barranquilla pipeline. Canacol in October
of 2016 executed a 100 MMscfpd ship of pay contract with Promigas in regards to
this second pipeline expansion.

With respect to management’s goal of drilling two oil exploration wells in
2017, the Corporation recently announced an oil discovery at Mono Capuchino 1,
which tested at a final rate of 1,013 barrels of oil per day, and has recently
spud the Pumara 1 light oil exploration well with results due in late April
2017. Canacol continues to maintain a large inventory of light oil drill ready
production and exploration opportunities that may accelerate should global oil
prices recover to a sustained level above US$ 50 / bbl.

Budget items include US$ 38 million of drilling related expenditures, US$ 8
million of 3D seismic activities, US$ 22 million on facilities, equipment and
flow line construction as we prepare for significant ramp up in our corporate
gas production, US$ 5 million on well workovers and shale activities, US$ 10
million on social investments, consultations and environmental activities in
preparation of 2018 exploration and production activities, and US$ 3.2 million
for our joint venture in Ecuador. Total budgeted 2017 capital expenditures are
within the Corporation’s anticipated 2017 funds from operations and opening
January 1, 2017 working capital of US$ 65 million.

Canacol is well positioned in 2017 to continue building production and revenues
despite the uncertainty and volatility associated with global oil prices,
especially with a near to midterm global outlook for oil prices of “lower for
longer”. It is important to point out that over 85% of our production revenues
is not subject to global oil price volatility, and that the Corporation’s debt
facility is not subject to redetermination should oil prices fall. This
financial strength, coupled with Canacol’s outstanding exploration drilling and
commercialization record of accomplishment, provides a solid platform to allow
us to reach our targets of 130 MMscfpd of gas production in December 2017. Upon
achieving 230 MMscfpd of gas production in December 2018, Canacol will become
the second largest producer of natural gas in Colombia behind the state oil
company.”

Remaining 2017 Exploration Drilling Program

Canahuate 1 Exploration Well

Esperanza Exploration and Production (“E&P”) Contract
Lower Magdalena Basin, Colombia
CNE Oil and Gas S.A.S. Operator WI 100%

The Canahuate 1 exploration well was spud on March 24, 2017. The Canahuate 1
well is located three kilometers (“km”) north of the Corporation’s Jobo gas
processing facility. The well is targeting potential gas-bearing sandstones
within the Cienaga de Oro (“CDO”) Formation. Over the past three years, six of
the seven exploration wells drilled by the Corporation on its gas blocks,
including the Esperanza E&P contract, have resulted in commercial gas
discoveries. The Canahuate 1 well will take approximately six weeks to drill
and test.

Toronja 1 Exploration Well

VIM21 E&P Contract
Lower Magdalena Basin, Colombia
CNE Oil and Gas S.A.S. Operator WI 100%

The Toronja 1 exploration well is anticipated to spud in late May 2017, and is
targeting potential gas-bearing sandstones within the shallow Porquero
Formation. The Toronja 1 well is located approximately three kms north of the
Jobo gas processing facility. The well will be the first follow-up exploration
location for the Porquero after the successful outcome of Nelson 6 exploration
well, which confirmed the Porquero as a new commercial play. The well will take
approximately five weeks to drill and test.

Pandereta 1 Exploration Well

VIM5 E&P Contract
Lower Magdalena Basin, Colombia
CNE Oil and Gas S.A.S. Operator WI 100%

The Pandereta 1 exploration well is anticipated to spud in September 2017, and
is targeting potential gas-bearing sandstones within the CDO. The Pandereta 1
well is located 13 kms east and on trend with the Corporation’s Clarinete gas
discovery made in 2014 and brought on production in 2015. The Pandereta 1 well
will take approximately six weeks to drill and test.

Pumara 1 Exploration Well

LLA23 E&P Contract
Llanos Basin, Colombia
CNE Oil and Gas S.A.S. Operator WI 100%

The Corporation spud the Pumara 1 exploration on March 31, 2017. The Pumara 1
exploration is located three km north of the Labrador field. The well is
targeting light oil bearing reservoirs within the proven producing C7, Mirador,
Gacheta and Ubaque reservoirs. Over the past four years, five of the six
exploration wells drilled by the Corporation on the LLA23 contract have
resulted in commercial producing light oil discoveries. The Pumara 1 well will
take approximately five weeks to drill and test, and if successful can be
placed on immediate permanent production via the Corporation’s oil processing
facilities located at Pointer.

Other 2017 Capital Projects

Guacharaca 3D Seismic Acquisition (VIM5 E&P Contract, Operator (100% WI))

The Corporation plans to acquire 155 km2 of 3D seismic commencing in the fourth
quarter of 2017. The objective of the seismic program is to advance exploration
leads presently defined on 2D seismic data to drill-ready prospects with a view
to supplementing the Corporation’s exploration portfolio of drill-ready
prospects currently defined on existing 3D seismic.

Jobo Plant (Esperanza E&P Contract, Operator (100% WI))

Over the course of the year, process optimization, debottlenecking and
improvements to water treatment and disposal will be undertaken at the
Corporation’s gas processing plant at Jobo. Works will be done to prepare the
plant in advance of the 130 MMscfpd contractual sales effective December 1,
2017.

Flow Line Construction (Esperanza E&P Contract, Operator (100% WI))

Works are underway to tie in 2016 exploration discoveries to the Jobo gas
processing plant including the 18 km Nispero flowline. In addition, a 3.5 km
flowline and a 10.5 km flowline are being installed to tie in development well
Nelson 8 and to loop the existing Betania to Jobo flowline, respectively.

Well Workovers (VMM2 E&P Contract, Non-Operator (40% WI))

Capital allocated to conduct workovers of two existing oil wells at the Mono
Arana field to enhance production performance.

Well Workover (VMM3 E&P Contract, Non-Operator (20% WI)

In the Pico Plata-1 exploration well drilled in 2015, the Corporation allocated
capital to conduct a series of DFITs over intervals in the La Luna shale
identified to be prospective from petrophysical analysis.

Canacol’s forecasted realized contractual oil and gas sales is expected to
average between 18,000 and 19,000 boepd, of which, realized contractual gas
sales is expected to average 85 MMscfpd (14,900 boepd) with an anticipated
average realized price of approximately US$ 5.00 / MMbtu (US$ 28.50 / boe). The
Corporation’s forecasted gas netback is approximately US$ 4.00 / Mscf (US$
22.80 / boe). Average gas price for 2017 has been impacted by the decrease in
the Guajira index (US$ 4.63 / MMbtu for 2017 versus US$ 6.17 / MMbtu for 2016)
that governs the sales contract of 16 MMscfpd to the Cerro Matoso ferronickel
mine. The price of the Guajira index is redetermined annually. Canacol
anticipates Colombian oil production to average approximately 2,500 bopd and
Ecuador oil production to average approximately 1,200 bopd in calendar 2017.

Canacol is an exploration and production company with operations focused in
Colombia, Ecuador, and Mexico. The Corporation’s common stock trades on the
Toronto Stock Exchange, the OTCQX in the United States of America, and the
Colombia Stock Exchange under ticker symbol CNE, CNNEF, and CNE.C, respectively.

This press release contains certain forward-looking statements within the
meaning of applicable securities law. Forward-looking statements are frequently
characterized by words such as “plan”, “expect”, “project”, “intend”,
“believe”, “anticipate”, “estimate” and other similar words, or statements that
certain events or conditions “may” or “will” occur, including without
limitation statements relating to estimated production rates from the
Corporation’s properties and intended work programs and associated timelines.
Forward-looking statements are based on the opinions and estimates of
management at the date the statements are made and are subject to a variety of
risks and uncertainties and other factors that could cause actual events or
results to differ materially from those projected in the forward-looking
statements. The Corporation cannot assure that actual results will be
consistent with these forward looking statements. They are made as of the date
hereof and are subject to change and the Corporation assumes no obligation to
revise or update them to reflect new circumstances, except as required by law.
Prospective investors should not place undue reliance on forward looking
statements. These factors include the inherent risks involved in the
exploration for and development of crude oil and natural gas properties, the
uncertainties involved in interpreting drilling results and other geological
and geophysical data, fluctuating energy prices, the possibility of cost
overruns or unanticipated costs or delays and other uncertainties associated
with the oil and gas industry. Other risk factors could include risks
associated with negotiating with foreign governments as well as country risk
associated with conducting international activities, and other factors, many of
which are beyond the control of the Corporation.

This press release contains non-GAAP measures such as EBITDAX, funds from
operations, working capital, operating netback per barrel and realized
contractual gas sales that do not have any standardized meaning under IFRS and
may not be comparable to similar measures presented by other companies.
Management uses these non-GAAP measures for its own performance measurement and
to provide shareholders and investors with additional measurements of the
Corporation’s performance and financial results.

Realized contractual gas sales is defined as gas produced and sold plus gas
revenues received from nominated take or pay contracts.

– END RELEASE – 12/04/2017

For further information:
Investor Relations
214-235-4798
IR@canacolenergy.com
canacolenergy.com

COMPANY:
FOR: CANACOL ENERGY LTD.
TSX SYMBOL: CNE
OTCQX SYMBOL: CNNEF
BVC SYMBOL: CNEC

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170412CC0009

Press Release from Marketwired 1-866-736-3779

Solar Alliance Completes Expansion of Sales Team as Part of Acquisition of U.S. Solar Assets

April 12, 2017 by The Canadian Press

FOR: SOLAR ALLIANCE ENERGY, INC.TSX VENTURE Symbol: SANOTCQB Symbol: SAENFDate issue: April 12, 2017Time in: 7:00 AM eAttention:
VANCOUVER, BC –(Marketwired – April 12, 2017) – Solar Alliance Energy, Inc.
(‘Solar Alliance’) or (the ‘Company’) (TSX VE…

Are Your Employees 'Engaged'? It's Essential for Your Company’s Success: Read Why HERE – Wendy Ferguson – BHRLR, CPHR

June 28, 2017April 11, 2017 by EnergyNow Media

By Wendy Ferguson – BHRLR, CPHR – Ferguson HR Consulting No matter how big or small your company is in Canada’s energy industry, your employees have to be engaged for your company to be successful. I can’t count how many times I’ve heard an interview candidate say that since they … Read more

Savanna Announces Receipt of Demand for Payment Pursuant to Second Lien Credit Facility

April 11, 2017 by The Canadian Press

FOR: SAVANNA ENERGY SERVICES CORP.TSX SYMBOL: SVYDate issue: April 11, 2017Time in: 9:12 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 11, 2017) – Savanna Energy Services
Corp. (“Savanna”) (TSX:SVY) announces it has received a notice (the “Noti…

Gas prices will rise this summer but should remain low

April 11, 2017 by The Canadian Press

NEW YORK — You didn’t think those super-low gas prices would last forever, did you?

The U.S. government says a rebound in oil prices means drivers will be paying more at the pump this summer than last year. But that will still be a bargain compared to just a few years ago.

The Energy Information Administration on Tuesday forecast that retail gas will cost an average of $2.46 a gallon from April through September, up from $2.23 a gallon over the summer of 2016.

The price of crude oil has risen about 15 per cent over the last year, although at $53 a barrel, oil still costs about half as much as it did in the middle of 2014. Prices tumbled after that because of a huge supply glut.

“Motorists have gotten used to gas prices under $3 a gallon and that will continue,” says Patrick DeHaan, senior petroleum analyst for the gas price tracking firm GasBuddy.

Gas prices rise over the summer as more people hit the road to take advantage of the warmer weather and school breaks. And while gas prices can vary a great deal depending on geography and other factors, the agency says it believes the average price of gas will rise to $2.39 a gallon this year, from $2.15 a gallon in 2016.

If that holds, the average U.S. household would spend about $200 more on gasoline than it did in 2016, the EIA said. But that imaginary average household would still save about $300 compared to average yearly spending on gas from 2012 to 2016.

Gas prices are now the highest they’ve been in about a year and a half, according to the American Automobile Association. Prices at the pump are now above $3 a gallon in some places, a barrier that is psychologically significant and keeps some people from driving as much as they would otherwise.

“Demand for gasoline likely will be flat or slightly lower than last year because of the increase in price,” DeHaan said.

Diesel prices are also expected to rise to $2.70 a gallon this year from $2.34 a gallon, but that’s also well below the average price of the fuel over the last five years. The U.S. now produces so much more oil than it did in years past that oil prices, and in turn gas prices, are much lower than they were a couple of years ago.

While DeHaan expects gas consumption to fall slightly, he said drivers will probably set another record for the amount of miles they drive because fuel efficiency has improved.

Marley Jay, The Associated Press

Jura Announces Release of Annual Filings and Increase in Reserves

April 11, 2017 by The Canadian Press

FOR: JURA ENERGY CORPORATIONTSX SYMBOL: JECDate issue: April 11, 2017Time in: 8:08 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 11, 2017) – Jura Energy Corporation
(“Jura”) (TSX VENTURE:JEC) today announced the filing on SEDAR of its
consolida…

Weekly Canadian Oil & Gas Industry Highlights – April 10, 2017

June 28, 2017April 11, 2017 by EnergyNow Media

April 10, 2017 Presented by POIM Consulting Group Major /Interesting Projects PENGROWTH Energy Corporation very large compression projects at Gas Plant SWAN HILLS SOUTH Seven Generations Energy Ltd. Large Gas battery 02-03-064-04W6 Rifle Shot Oil Corp install Pump at existing facility 01-18-039-06W4 Northern Blizzard Resources Inc Custom Treating Facility Kindersley BONTERRA Energy Corp New PAD … Read more

Trinidad Drilling First Quarter 2017 Results and Conference Call

April 11, 2017 by The Canadian Press

FOR: TRINIDAD DRILLING LTD.TSX SYMBOL: TDGDate issue: April 11, 2017Time in: 5:27 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 11, 2017) –
NOT FOR DISTRIBUTION TO UNITED STATES NEWSWIRE SERVICES OR FOR DISSEMINATION IN
THE UNITED STATES.
Trini…

Todd Slawson Announces Update to Shareholdings of PetroShale Inc.

April 11, 2017 by The Canadian Press

FOR: PETROSHALE INC.TSX VENTURE SYMBOL: PSHDate issue: April 11, 2017Time in: 5:16 PM eAttention:
DENVER, COLORADO–(Marketwired – April 11, 2017) – Mr. Todd Slawson announced
today that as a result of the recently announced closing of a public offerin…

Traverse Energy Announces 2016 Year End Results

April 11, 2017 by The Canadian Press

FOR: TRAVERSE ENERGY LTD.TSX VENTURE SYMBOL: TVLDate issue: April 11, 2017Time in: 5:10 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 11, 2017) – Traverse Energy Ltd.
(“Traverse” or “the Company”) (TSX VENTURE:TVL) presents financial and
operat…

Changfeng Application for Natural Gas Selling Price Increase Approved by Hainan Provincial Government

April 11, 2017 by The Canadian Press

FOR: CHANGFENG ENERGY INC.
TSX VENTURE SYMBOL: CFY

Date issue: April 11, 2017
Time in: 5:05 PM e

Attention:

TORONTO, ONTARIO–(Marketwired – April 11, 2017) – Changfeng Energy Inc., (TSX
VENTURE:CFY) (“Changfeng” or the “Company”), an energy service provider in
China, announced today that the Company has received Hainan provincial
regulatory approval (“the approval”) to increase natural gas sale price to its
residential users, and non-residential users in Sanya City, Hainan Province,
China.

With the approval, the maximum selling price to residential users increased, on
average, 21%, while the maximum selling price to non-residential customers has
increased approximately 8.9%. The Company is entitled to adjust its selling
price based on its gas purchase cost and the market environment under the
maximum selling price. This selling price increase is subject to the Sanya City
Price Bureau’s final approval before implementation.

The approval of increase in natural gas selling price could increase the sales
of the Company’s operation in Sanya Region.

Changfeng Energy Inc.

Changfeng Energy Inc. is a natural gas service provider with operations located
throughout the People’s Republic of China. The Company services industrial,
commercial and residential customers, providing them with natural gas for
heating purposes and fuel for transportation. The Company has developed a
significant natural gas pipeline network as well as urban gas delivery
networks, stations, substations and gas pressure regulating stations in Sanya
City & Haitang Bay. Through its network of pipelines, the Company provides safe
and reliable delivery of natural gas to both homes and businesses. The Company
is headquartered in Toronto, Ontario and its shares trade on the Toronto
Venture Exchange under the trading symbol “CFY”. For more information, please
visit the Company website at www.changfengenergy.com.

Forward-Looking Statements

Information set forth in this news release may involve forward-looking
statements under applicable securities laws. The forward-looking statements
contained herein are expressly qualified in their entirety by this cautionary
statement. The forward-looking statements included in this document are made as
of the date of this document and the Company disclaims any intention or
obligation to update or revise any forward-looking statements, whether as a
result of new information, future events or otherwise, except as expressly
required by applicable securities legislation. Although Management believes
that the expectations represented in such forward-looking statements are
reasonable, there can be no assurance that such expectations will prove to be
correct. Such forward-looking statements involve known and unknown risks,
uncertainties, assumptions and other factors that may cause the actual results,
performance or achievements to differ materially from the anticipated results,
performance or achievements or developments expressed or implied by such
forward-looking statements. This news release does not constitute an offer to
sell or solicitation of an offer to buy any of the securities described herein
and accordingly undue reliance should not be put on such. Neither TSX Venture
Exchange nor its Regulation Services Provider (as that term is defined in the
policies of the TSXV) accepts responsibility for the adequacy or accuracy of
this release.

– END RELEASE – 11/04/2017

For further information:
Changfeng Energy Inc.
Mr. Yan Zhao CPA. CA. MBA
Chief Financial Officer
647.313.0066
yan.zhao@changfengenergy.cn
OR
Changfeng Energy Inc.
Ms. Ann S.Y. Lin
VP, Corporate Development and Corporate Secretary
647.313.0066
siyin.lin@changfengenergy.cn

COMPANY:
FOR: CHANGFENG ENERGY INC.
TSX VENTURE SYMBOL: CFY

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170411CC0077

Press Release from Marketwired 1-866-736-3779

M. Bruce Chernoff Acquires Securities of PetroShale Inc.

April 11, 2017 by The Canadian Press

FOR: PETROSHALE INC.TSX VENTURE SYMBOL: PSHDate issue: April 11, 2017Time in: 4:03 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 11, 2017) – On April 11, 2017 Mr. M.
Bruce Chernoff (“Chernoff”) acquired, through Hawthorne Energy Ltd., an entity…

Pembina Pipeline looking to build West Coast terminal near Prince Rupert, B.C.

April 11, 2017 by The Canadian Press

CALGARY — Pembina Pipeline Corp. (TSX:PPL) has signed a non-binding letter of intent to develop a liquefied petroleum gas export terminal on Watson Island, south of Prince Rupert, B.C.

The Calgary-based pipeline operator signed the agreement with Prince Rupert Legacy Inc., a wholly owned subsidiary of the City of Prince Rupert.

The company said it has started a site assessment for the West Coast project and engagement with stakeholders including aboriginal communities.

Initial assessments indicate the development of an export terminal with a capacity of about 20,000 barrels per day of LPG at a capital cost ranging between $125 million and $175 million, Pembina said.

The company said it expects a project timeline of two years from a final investment decision.

The project is still subject to completion of design and engineering requirements, appropriate definitive agreements, environmental and regulatory permits and the approval of Pembina’s board.

The Canadian Press

Divers find natural gas pipeline leak in Alaska’s Cook Inlet

April 10, 2017 by The Canadian Press

ANCHORAGE, Alaska — The owner of a pipeline spewing natural gas in Alaska’s Cook Inlet says dive crews have located the leak.

The Hilcorp Alaska LLC pipeline has leaked hundreds of thousands of cubic feet of processed natural gas since mid-December. The leak was spotted from the air Feb. 7.

The 8-inch (20-centimetre) diameter pipeline supplies gas for power to four production platforms.

Hilcorp spokeswoman Lori Nelson in an announcement says divers discovered a 2-inch (5-centimetre) hole at bottom of the pipeline where it rests on a boulder embedded in the sea floor.

Divers are preparing the site for installation of a temporary clamp.

A more permanent fix will follow.

Nelson says the line will not be put back into service until permanent repairs are completed and regulators approve restarting the line.

Dan Joling, The Associated Press

Environmental group appeals New Jersey gas pipeline approval

April 10, 2017 by The Canadian Press

ATLANTIC CITY, N.J. — An environmental group is appealing the approval of a hotly contested natural gas pipeline through the ecologically sensitive New Jersey Pinelands region by the state agency created to protect the area.

The Sierra Club filed an appeal Monday of a Feb. 24 decision by the New Jersey Pinelands Commission to approve a natural gas pipeline through the federally protected reserve.

The pipeline is designed to help a power plant in New Jersey switch from coal to gas.

New Jersey Sierra Club Director Jeff Tittel says the commission failed to follow its own guidelines that require any project in the Pinelands to primarily benefit people living there. He says the gas plant is largely outside the Pinelands preserve.

The commission declined to comment Monday.

Wayne Parry, The Associated Press

A Stable Working Structure is the Key to Your Success – T.A. Cook

June 28, 2017April 10, 2017 by EnergyNow Media

John Natarelli, Project Manager T.A. Cook Consultants, Inc. Without a stable working structure, an organization is much more likely to fail than succeed. Many different factors can impact how an organization is structured. However, the two most important factors that will affect structure are organizational objectives and the strategies used to achieve … Read more

Hundreds of icebergs clog shipping lanes, forcing ships to reroute

April 10, 2017 by The Canadian Press

ST. JOHN’S, N.L. — More icebergs have drifted into major shipping lanes off Newfoundland, forcing ships to go far out of their way to steer clear of the massive ice mountains.

“It’s the only place in the world where icebergs intersect in a major shipping lane like that,” Gabrielle McGrath, commander of the United States Coast Guard International Ice Patrol, said Monday from her office in New London, Connecticut.

“The ships are having to go out of their way to get around that iceberg limit … so it’s taking them a lot longer to get across the Atlantic.”

McGrath said 616 icebergs have already moved into the North Atlantic lanes so far this season, compared to 687 last year by the late-September season’s end.

The influx started in late March, she said.

There were 37 icebergs observed on March 27, but a low pressure system of strong counter-clockwise winds dramatically shifted big ice originating from Greenland glaciers farther south down the eastern Newfoundland coast.

As a result, three days later there were 272 icebergs in those shipping lanes — roughly the same area where the Titanic went down in 1912 after striking an iceberg.

Canadian Coast Guard Ice Operations said there were about 481 icebergs in the area as of last Thursday.

Those kinds of numbers are usually not seen until late May or early June, with the average for this time of year at about 80.

McGrath said the way things are going, the number will exceed last year’s and could approach some of the record highs depending on water temperatures and winds. In 2014, there were 1,546 icebergs in the shipping lanes, making it the sixth most severe season on record since 1900. There were 1,165 icebergs in 2015.

Chad Allen of the Shipping Federation of Canada said ships tend to move further south to avoid colliding with the icebergs, which increases costs and makes scheduling more challenging.

“A couple of years ago we had ships that would certainly extend several hundred miles off their track just to avoid those icebergs,” he said. “There’s a cost component to that, there are scheduling concerns and with the increased distances, there is more fuel being burned.”

McGrath said she has not heard of any ships striking an iceberg after heeding the patrol’s warnings, but a floating oil platform off Newfoundland had a close call last month with an iceberg the size of a small office building.

Husky Energy said the medium sized iceberg — described as 40 metres wide, 60 metres long and standing eight metres above the waterline — came within 180 metres of the rig, causing Husky to de-pressurize production wells and flush flowlines with treated seawater as crew mustered in preparation for a potential disconnect.

The ice patrol was formed after the Titanic disaster in 1912, and works with Canadian partners to track icebergs in North Atlantic shipping lanes.

The Canadian Press

WesternZagros Announces 42% Production Increase at Sarqala-1, Further Increases Anticipated

April 10, 2017 by The Canadian Press

FOR: WESTERNZAGROS RESOURCES LTD.TSX VENTURE SYMBOL: WZRDate issue: April 10, 2017Time in: 7:30 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 10, 2017) –
NOT FOR DISTRIBUTION TO U.S. NEWSWIRE SERVICES OR DISSEMINATION IN THE UNITED
STATES
Weste…

Solar Alliance Announces Private Placement

April 10, 2017 by The Canadian Press

FOR: SOLAR ALLIANCE ENERGY INC.TSX VENTURE Symbol: SANOTCQB Symbol: SAENFDate issue: April 10, 2017Time in: 7:00 AM eAttention:
VANCOUVER, BC –(Marketwired – April 10, 2017) –
NOT FOR DISTRIBUTION TO UNITED STATES NEWSWIRE SERVICES OR FOR DISSEMINATIO…

Trans Mountain agreement includes investment deadline, hiring priorities

April 8, 2017 by The Canadian Press

MERRITT, B.C. — A deal reached between British Columbia and Trans Mountain reveals new details about Kinder Morgan’s timeline to approve investments for a proposed oil pipeline expansion and requirements to hire local workers.

The agreement, signed April 6, says the Kinder Morgan board of directors must reach a final investment decision by June 30 with news communicated by July 2 for the project to go ahead.

The project would twin an existing pipeline between Edmonton and Burnaby, B.C., tripling its capacity and increasing tanker traffic in the Burrard Inlet seven-fold.

The company said last month the expansion would cost an estimated $7.4 billion, an increase from previous estimates in order to meet conditions imposed by the National Energy Board.

The agreement also includes a policy requiring the company to consider hiring B.C. businesses and First Nations first for the construction and maintenance of the project within the province.

But local businesses and workers are prioritized only if they meet Kinder Morgan’s requirements for safety and expertise, offer competitive pricing and aren’t at odds with the company’s existing obligations.

A statement from the province didn’t specify the number of jobs expected, however, Natural Gas Minister Rich Coleman called the agreement unprecedented.

A spokesperson for Trans Mountain said in a statement Saturday, “Next steps for the project include arranging acceptable financing and a final investment decision by Kinder Morgan.”

Apart from the June 30 deadline, the spokesperson said a date has not yet been set for the company’s board to reach a final investment decision.

The Canadian Press

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June 28, 2017April 7, 2017 by EnergyNow Media

Canada has always been a leader in doing business internationally in different energy markets. So, it’s no surprise to learn that more companies are seeking out information on expanding into new and challenging foreign areas. The Country Market Seminar Series at Global Petroleum Show, sponsored in part by the Canadian Global Exploration Forum (CGEF), is … Read more

Federal regulators say pipeline’s effect would be ‘limited’

April 7, 2017 by The Canadian Press

TRENTON, N.J. — The environmental impacts of a proposed roughly 120-mile (193-kilometre), $1.2 billion natural gas pipeline from northeastern Pennsylvania to New Jersey would be “effectively limited,” federal regulators said Friday.

The Federal Energy Regulatory Commission issued its final environmental impact study for the PennEast pipeline and outlined several areas of concern, including trace amounts of arsenic in some rocks the pipeline would cross and potential threats to endangered species.

But the report says PennEast is proposing mitigation efforts like well monitoring and avoiding endangered animal habitats.

“We conclude that the cumulative impacts associated with the project, when combined with other known or reasonably foreseeable projects, would be effectively limited,” the report said.

The report comes after Republican President Donald Trump advanced the Keystone XL and Dakota Access oil pipeline projects, which had become battles in a bigger political fight over environmental concerns.

The PennEast project is fiercely opposed by environmental groups who say it would irreversibly damage the landscape. New Jersey Sierra Club director Jeff Tittel called the report a “sham.”

The Federal Energy Regulatory Commission “has shown they are nothing but a front for the gas industry that they’re supposed to regulate,” Tittel said.

A Commission spokeswoman declined to respond because the matter is pending before the panel.

PennEast spokeswoman Pat Kornick praised the report and says it’s the final major federal regulatory hurdle.

The next step for the project would be for the commission to determine whether there’s a need for the project, which would amount to a federal green light for the pipeline. That step could be delayed because the commission lacks the quorum required to vote on such approvals.

Permits are also still pending with the New Jersey Department of Environmental Protection.

PennEast hopes for the pipeline to be operational in the second half of 2018, according to Kornick.

The pipeline would originate in Dallas, Luzerne County, Pennsylvania, and end at near Pennington, Mercer County, New Jersey.

Michael Catalini, The Associated Press

Strategic Oil & Gas Ltd. Announces Issuance of Stock Options and Provides Operations Update

April 7, 2017 by The Canadian Press

FOR: STRATEGIC OIL & GAS LTD.
TSX VENTURE SYMBOL: SOG

Date issue: April 07, 2017
Time in: 5:46 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 7, 2017) – Strategic Oil & Gas Ltd.
(“Strategic” or the “Company”) (TSX VENTURE:SOG) announces the issuance of
stock options and provides an operations update.

OPERATIONS UPDATE

Strategic is currently in the process of completing the five Muskeg horizontal
wells drilled in the first quarter, and will provide further updates as the
wells come onstream.

STOCK OPTION GRANT

The Company issued 1.523 million stock options to directors, officers,
employees and consultants. Each option entitles the holder to acquire one
common share of the Company for a period of five years at a price of $2.65 per
share. These options were issued in accordance with the Strategic’s incentive
stock option plan. The Company currently has 46.4 million shares outstanding.

ABOUT STRATEGIC OIL & GAS

Strategic is a junior oil and gas company committed to becoming a premier
northern oil and gas operator by exploiting its light oil assets primarily in
northern Alberta. The Company relies on its extensive subsurface and reservoir
experience to develop its asset base and grow production and cash flows while
managing risk. The Company maintains control over its resource base through
high working interest ownership in wells, construction and operation of its own
processing facilities and a significant undeveloped land and opportunity base.
Strategic’s primary operating area is at Marlowe, Alberta. Strategic’s common
shares trade on the TSX Venture Exchange under the symbol SOG.

ADDITIONAL INFORMATION

Additional information is also available at www.sogoil.com and at www.sedar.com.

Reader Advisories

This news release includes certain information, with management’s assessment of
Strategic’s future plans and operations, and contains forward-looking
statements which may include some or all of the following: (i) timing to
complete and put new wells on production; (ii) timing of future market updates;
and (iii) future capital projects to be undertaken, which are provided to allow
investors to better understand the Company’s business. By their nature,
forward-looking statements are subject to numerous risks and uncertainties;
some of which are beyond Strategic’s control, including the impact of general
economic conditions, industry conditions, volatility of commodity prices,
currency fluctuations, imprecision of reserve estimates, environmental risks,
changes in environmental tax and royalty legislation, competition from other
industry participants, the lack of availability of qualified personnel or
management, stock market volatility and ability to access sufficient capital
from internal and external sources, and other risks and uncertainties described
under the heading ‘Risk Factors’ and elsewhere in the Company’s Annual
Information Form for the year ended December 31, 2016 and other documents filed
with Canadian provincial securities authorities and are available to the public
at www.sedar.com. Readers are cautioned that the assumptions used in the
preparation of such information, although considered reasonable at the time of
preparation, may prove to be imprecise and, as such, undue reliance should not
be placed on forward-looking statements. The principal assumptions Strategic
has made includes security of land interests; drilling cost stability; royalty
rate stability; oil and gas prices to remain in their current range; finance
and debt markets continuing to be receptive to financing the Company and
industry standard rates of geologic and operational success. Actual results
could differ materially from those expressed in, or implied by, these
forward-looking statements. Strategic disclaims any intention or obligation to
update or revise any forward-looking statements, whether as a result of new
information, future events or otherwise, except as required by law.

– END RELEASE – 07/04/2017

For further information:
Strategic Oil & Gas Ltd.
Gurpreet Sawhney
President and CEO
403.767.2949
403.767.9122 (FAX)
OR
Strategic Oil & Gas Ltd.
Aaron Thompson
Chief Financial Officer
403.767.2952
403.767.9122 (FAX)
www.sogoil.com

COMPANY:
FOR: STRATEGIC OIL & GAS LTD.
TSX VENTURE SYMBOL: SOG

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170407CC0044

Press Release from Marketwired 1-866-736-3779

AltaGas Ltd. to Hold Annual Meeting of Shareholders and Issue First Quarter 2017 Results

April 7, 2017 by The Canadian Press

FOR: ALTAGAS LTD.TSX SYMBOL: ALADate issue: April 07, 2017Time in: 5:30 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 7, 2017) – AltaGas Ltd. (“AltaGas”)
(TSX:ALA) invites investors, potential investors, members of the media and all
interested …

ENGIE and Axium Secure 50-year Comprehensive Energy Management Contract with The Ohio State University

April 7, 2017 by The Canadian Press

FOR: ENGIE NORTH AMERICA INC.

AND AXIUM INFRASTRUCTURE US INC.

Date issue: April 07, 2017
Time in: 4:59 PM e

Attention:

HOUSTON, TEXAS and NEW YORK, NEW YORK and MONTREAL, QUEBEC–(Marketwired –
April 7, 2017) – ENGIE North America Inc. and Axium Infrastructure US have won
a 50-year concession valued at $1.165 billion USD to address The Ohio State
University’s energy sustainability goals for its 485-building campus in
Columbus, Ohio, one of the largest university campuses in the United States.
Following detailed reviews by groups composed of students, faculty, and staff
who identified the ENGIE-Axium proposal as the top bid, the university’s Board
of Trustees approved the contract award on April 7, culminating a more than
two-year-long process in which 40 interested parties initially participated.

Having worked as business partners in Canada for the past five years managing a
portfolio of large-scale wind and solar installations totaling 680 MW, ENGIE
and Axium are long-term operators and investors. Founded in 1870, Ohio State
enrolls nearly 60,000 students on its Columbus campus, and welcomes
approximately 100,000 people every weekday during the academic year.

“We’re excited for the opportunity to deploy our experience in energy
efficiency, production, procurement, and commodity risk management to support
Ohio State in its quest to become an international leader in sustainability
while providing new resources to enhance its academic mission,” said Frank
Demaille, CEO of ENGIE North America. “With innovation, performance, and safety
underpinning all of our endeavors, we are eager to work with the Ohio State
utility team and with faculty, staff, and students on new energy research and
technology commercialization through a state-of-the-art Energy Advancement and
Innovation Center that we will build.”

“Axium is thrilled to join forces with ENGIE to deliver world class energy
services to Ohio State, and to advance the visionary sustainability objectives
put forward by the Ohio State community,” said Thierry Vandal, President of
Axium Infrastructure US.

Signature elements of the Comprehensive Energy Management Project include:

/T/

— Operation and optimization of the university’s utility system, including

Energy Conservation Management Services leveraging the existing system
and development of future capital improvement projects to improve the
university’s energy efficiency by 25% within 10 years.

— Construction of a new Energy Advancement and Innovation Center for

energy research and commercialization. The Center would create a living
laboratory where faculty, students, alumni, entrepreneurs, industry
experts, and ENGIE researchers can collaborate on next-generation
technologies and services in areas such as smart energy systems,
renewable energy, and green mobility. The Center will be ENGIE’s first
research facility in North America, with connectivity across ENGIE’s
worldwide research and industry network.

/T/

“This partnership positions us as an international leader in energy and
sustainability and further strengthens Ohio State as a national flagship public
research university,” said Ohio State President Michael V. Drake.

“We are entering a relationship with Ohio State that will span generations,”
Demaille concluded. “ENGIE and Axium look forward to uniting our ambitions with
the university and surrounding community to build a cleaner, more efficient,
and more innovative energy future in the years to come.”

About ENGIE and Axium

ENGIE manages a range of energy businesses in the United States and Canada,
including electricity generation and cogeneration, natural gas and liquefied
natural gas (LNG) distribution and sales, retail energy sales, and
comprehensive services to help customers run their facilities more efficiently
and optimize energy use and expense. Nearly 100 percent of the company’s power
generation portfolio produces no carbon emissions or very few. Globally, the
company is present in 70 countries and employs 153,090 people, including 1,000
researchers in 11 R&D centers. For more information, please visit
www.engie-na.com, @ENGIENorthAm, and www.engie.com.

Axium is a long-term, buy-and-hold infrastructure investment firm with over
$1.5 billion in assets under management, as well as approximately $1 billion in
managed co-investments. Axium currently holds a diversified portfolio of power
and energy, transportation, and social infrastructure assets, including
substantial investments in renewable energy to date, with interests in over 2.5
GW of wind, solar and hydroelectric power generation across North America.

– END RELEASE – 07/04/2017

For further information:
ENGIE Press contacts
Julie Vitek
Julie.vitek@na.engie.com
713 636 1962
Twitter : @ENGIEgroup
OR
Marie-Claude Cabana
marie-claude.cabana@engie.com
514 876-8748
OR
Axium Press contact
Anne-Sophie Roy
asroy@axiuminfra.com
514 954 3781

COMPANY:
FOR: ENGIE NORTH AMERICA INC.

AND AXIUM INFRASTRUCTURE US INC.

INDUSTRY: Energy and Utilities – Alternative Energy
RELEASE ID: 20170407CC0036

Press Release from Marketwired 1-866-736-3779

Sign of the times? Solar panels power Kentucky Coal Museum

April 7, 2017 by The Canadian Press

FRANKFORT, Ky. — Don’t look to the Kentucky Coal Museum to bring coal back.

The museum is installing solar panels on its roof, part of a project aimed at lowering the energy costs of one of the city’s largest electric customers. It’s also a symbol of the state’s efforts to move away from coal as its primary energy source as more coal-fired power plants are replaced by natural gas. The state legislature recently lifted its decades-old ban on nuclear power.

“It’s a little ironic or coincidental that you are putting solar green energy on a coal museum,” said Roger Noe, a former state representative who sponsored the legislation that created the coal museum. “Coal comes from nature, the sun rays come from nature so it all works out to be a positive thing.”

The museum is in Benham, once a coal camp town whose population peaked at about 3,000, according to 85-year-old Mayor Wanda Humphrey. Today, it has about 500 people, and Humphrey says she is the mayor because no one else wants the job.

“It takes our entire police force — we have one person, we have Ryan — to get me in the building and back out,” she said.

The town’s second building was a company commissary known as the “big store,” where Humphrey would visit every day after school to order an RC Cola and a bag of peanuts, charged to her father’s account. Today, that building houses the Kentucky Coal Museum, which opened in 1994 with the help of some state funding. The museum houses relics from the state’s coal mining past, including some items from the personal collection of “Coal Miner’s Daughter” country singer Loretta Lynn.

It’s also the best place in town to get the most direct sunlight, which made it an ideal location for solar panels.

“The people here are sort of in awe of this solar thing,” Humphrey said.

The Southeast Community and Technical College, which owns the museum, expects the solar panels to save between $8,000 and $10,000 a year on energy costs, according to spokesman Brandon Robinson.

Adam Beam, The Associated Press

Augusta Announces Development of New Portable EFM System

April 7, 2017 by The Canadian Press

FOR: AUGUSTA INDUSTRIES INC.TSX VENTURE SYMBOL: AAODate issue: April 07, 2017Time in: 9:00 AM eAttention:
TORONTO, ONTARIO–(Marketwired – April 7, 2017) – Augusta Industries Inc. (the
“Corporation”) (TSX VENTURE:AAO) is pleased to announce that its wh…

Enbridge Recommends Shareholders Reject TRC Capital’s “Mini-Tender Offer”

April 7, 2017 by The Canadian Press

FOR: ENBRIDGE INC.TSX SYMBOL: ENBNYSE SYMBOL: ENBDate issue: April 07, 2017Time in: 9:00 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 7, 2017) – Enbridge Inc.
(TSX:ENB)(NYSE:ENB) (Enbridge) has been notified of an unsolicited mini-tender
offer…

Precision Drilling Corporation Announces Retirement of Board Chair and Appointment of Incoming Chair

April 7, 2017 by The Canadian Press

FOR: PRECISION DRILLING CORPORATIONTSX SYMBOL: PDNYSE SYMBOL: PDSDate issue: April 07, 2017Time in: 7:00 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 7, 2017) – Precision Drilling
Corporation (“Precision” or the “Company”) (TSX:PD)(NYSE:PDS) a…

Solar Alliance Achieves Profitability for U.S. Operations for March 2017

April 7, 2017 by The Canadian Press

FOR: SOLAR ALLIANCE ENERGY, INC.TSX VENTURE Symbol: SANOTCQB Symbol: SAENFDate issue: April 07, 2017Time in: 7:00 AM eAttention:
VANCOUVER, BC –(Marketwired – April 07, 2017) – Solar Alliance Energy, Inc.
(‘Solar Alliance’) or (the ‘Company’) (TSX VE…

Big deficit, mounting debt but no tax hikes in Newfoundland and Labrador budget

April 7, 2017April 6, 2017 by The Canadian Press

ST. JOHN’S, N.L. — Taxpayers who helped pull Newfoundland and Labrador from a fiscal cliff got a slight break in the latest provincial budget, but debt will soar even as costs are slightly cut.

The $8.1-billion spending plan released Thursday has no tax or fee hikes and trims expenses by $283 million. It forecasts a $778-million deficit, down from $1.1 billion last year.

Higher-than-expected offshore oil royalties helped brighten a bleak financial picture and there were no deep public-sector job cuts as widely feared. But critics were quick to say the governing Liberals could have done more.

“We still have a massive spending problem,” said Richard Alexander, executive director of the Newfoundland and Labrador Employers’ Council. “We still have a fiscal crisis.

“Taxpayers … have bailed out this government basically from bankruptcy.”

Finance Minister Cathy Bennett said the province will be in the red for several more years before returning to surplus in 2022-23. Her budget last April — the first for the Liberals after they took office in late 2015 — was rife with tax and fee hikes on everything from books to ferry rides.

It became a lightning rod for public fury as government approval ratings tanked. Bennett has acknowledged tax fatigue but said Thursday there will be more belt-tightening.

“We continue to have a spending problem,” she told a news conference. “We are grateful that oil revenues continue to help us but it simply highlights the fact that we cannot afford the government services we have now with general revenue alone. We must continue to reduce spending in the years ahead.”

Still, the budget includes cutting an unpopular tax on gasoline by 8.5 cents per litre as of June 1 and another four cents on Dec. 1.

It also says there will be new legislation to freeze wages for public-sector managers and non-union workers. The province recently announced almost 400 management jobs will be eliminated.

Bennett said she anticipates no “massive layoffs” among other public-sector staff but bargaining is underway with several union groups.

Alexander said there will have to be sacrifice.

“Wages in the public sector are 27 per cent higher than the rest of Atlantic Canada. There’s room for unions to make concessions on those things. If they do that, it will mean fewer job layoffs in the future.”

The budget forecasts net debt will rise by almost $1 billion to $15.2 billion this fiscal year for a population of just 527,000 people.

About 13 cents of every tax dollar now goes to debt servicing, Alexander said. “We’re spending more on interest for the province’s credit card than we are on education.”

Bennett concedes it’s a staggering amount that, on a per capita basis, far exceeds other provinces.

“We need to continue to work on lowering the cost of delivering services and lowering the cost of borrowing,” she said.

Bennett spoke with the province’s main credit rating agencies prior to the budget and said she does not expect a repeat of recent downgrades that rack up interest.

The governing Liberals have trimmed almost $500 million in spending since taking office, she added. Bennett said those results have come from efficiencies and not diminished government services — a claim opposition critics have challenged.

The province has been financially hammered since oil prices collapsed from US$115 a barrel starting in mid-2014. Bennett had counted on an average oil price of about US$45 for the last fiscal year but prices were slightly higher.

Brent crude was trading early Thursday at about US$54 a barrel.

Higher prices and production put just over $962 million into provincial coffers last year, almost double what was forecast. Almost $882 million in offshore oil royalties are expected this year.

Bennett has anchored this year’s budget on an average oil price of US$56 a barrel, drawing on 30 forecast reports.

She has also asked Crown corporation Nalcor Energy to find savings to help lower electricity rates starting in 2020-21.

It’s a measure to offset another major drain on provincial finances: the delayed $12-billion Muskrat Falls hydroelectric project in Labrador. It’s almost double the cost forecast when the former Progressive Conservative government approved it in 2012. It’s also expected to add as much as $150 a month to an average heating bill when it comes online in about three years.

The province has borrowed $4.9 billion since 2016 to get through a funding crunch caused by over-reliance on once-lucrative offshore oil earnings, Bennett said. Borrowing will be down to $400 million this year, she added.

“I’m confident that the work we’re doing is getting us on the right track.”

Outside the legislature, demonstrators who gathered for a tail-gate style barbecue and protest said more tax relief can’t come soon enough.

“This government is putting the people in the hole,” said Andrew Young, a 66-year-old retiree. “The poor people can’t survive anymore. It’s too high, the taxes. It’s ridiculous.”

Follow @suebailey on Twitter.

Sue Bailey, The Canadian Press

CORRECTION FROM SOURCE/ATCO Announces Dennis DeChamplain as Chief Financial Officer

April 6, 2017 by The Canadian Press

FOR: ATCO LTD.
TSX SYMBOL: ACO.X
TSX SYMBOL: ACO.Y

Date issue: April 06, 2017
Time in: 8:31 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 6, 2017) – ATCO Ltd.
(TSX:ACO.X)(TSX:ACO.Y) – A correction from source has been issued for the
release disseminated April 6 2017 at 7:16 PM ET. The complete and corrected
release follows:

Today, ATCO announced the appointment of Dennis DeChamplain to the role of
Senior Vice President & Chief Financial Officer, effective June 1, 2017. Mr.
DeChamplain will assume the role from Brian Bale, who will be retiring after
more than 35 years with the company. Mr. Bale will continue in his role until
June 1, working alongside Mr. DeChamplain to ensure a smooth and seamless
transition.

Since his appointment to Chief Financial Officer in 2009, Mr. Bale’s
achievements have been both numerous and remarkable. During his tenure, ATCO’s
asset base grew from $10 billion in 2009 to $20 billion today. He was the
driving force behind the single largest long-dated corporate bond on record in
Canada – the issuance of a $1 billion, 4.085 per cent, 30-year bond by CU Inc.
– and was instrumental in navigating the $1 billion acquisition of ATCO Gas
Australia in 2011.

“Brian’s vision, stalwart leadership and unwavering courage have long defined
our financial success and enabled ATCO to not simply weather recent economic
turmoil, but emerge a more resilient and focused organization,” said Nancy
Southern, ATCO’s President, Chair & Chief Executive Officer. “Brian has served
our Share Owners with great distinction, and I know that I speak on behalf of
all ATCO constituents when I wish him well in his retirement and welcome Dennis
DeChamplain in his role as the corporation’s new Chief Financial Officer on
June 1.”

Mr. DeChamplain joined ATCO in 1992 and has held progressively senior
financial, regulatory, and business planning positions throughout the company.
Since 2015, he has overseen the financial management of ATCO’s Electricity
Global Business Unit in the role of Senior Financial Officer, providing
exceptional financial leadership and management of the group’s diversified
global operations in electricity generation, transmission and distribution.

“Dennis has proven himself time and again to be an extraordinarily insightful,
dedicated and resourceful leader,” said Ms. Southern. “I have the utmost
confidence that he will maintain our decades-long track record of enduring
financial strength with an unwavering focus on creating value for our Share
Owners.”

Mr. DeChamplain was born and educated in Edmonton, and graduated from the
University of Alberta in 1985 where he obtained a Bachelor of Commerce degree.
He obtained his Chartered Accountant designation in 1988 and is a member of
both the Alberta and Canadian Chartered Professional Accountants.

Forward-Looking Information:

Certain statements contained in this news release may constitute
forward-looking information. Forward-looking information is often, but not
always, identified by the use of words such as “anticipate”, “plan”,
“estimate”, “expect”, “may”, “will”, “intend”, “should”, and similar
expressions.

Forward-looking information involves known and unknown risks, uncertainties and
other factors that may cause actual results or events to differ materially from
those anticipated in such forward-looking information.

The Company’s actual results could differ materially from those anticipated in
this forward-looking information as a result of regulatory decisions,
competitive factors in the industries in which the Company operates, prevailing
economic conditions, and other factors, many of which are beyond the control of
the Company.

The Company believes that the expectations reflected in the forward-looking
information are reasonable, but no assurance can be given that these
expectations will prove to be correct and such forward-looking information
should not be unduly relied upon.

Any forward-looking information contained in this news release represents the
Company’s expectations as of the date hereof, and is subject to change after
such date. The Company disclaims any intention or obligation to update or
revise any forward-looking information whether as a result of new information,
future events or otherwise, except as required by applicable securities
legislation.

– END RELEASE – 06/04/2017

For further information:
Media Inquiries:
Spencer Forgo
Manager, External Communications
(403) 662-8467

COMPANY:
FOR: ATCO LTD.
TSX SYMBOL: ACO.X
TSX SYMBOL: ACO.Y

Press Release from Marketwired 1-866-736-3779

Cenovus achieves key acquisition financing milestones

April 6, 2017 by The Canadian Press

FOR: CENOVUS ENERGY INC.
TSX Symbol: CVE
NYSE Symbol: CVE

Date issue: April 06, 2017
Time in: 8:02 PM e

Attention:

Remains committed to strengthening its balance sheet

CALGARY, AB –(Marketwired – April 06, 2017) – Cenovus Energy Inc. (TSX: CVE)
(NYSE: CVE) has made significant progress executing on its previously
announced financing plan for the company’s $17.7 billion purchase of assets in
Western Canada from ConocoPhillips. The acquisition is expected to close in
the second quarter of this year.

Since the agreement was announced on March 29, 2017, Cenovus has successfully
completed a planned $3.0 billion bought-deal common share financing and priced
a US$2.9 billion offering of senior notes. The company is also issuing common
shares to ConocoPhillips and intends to use a portion of its existing cash on
hand and available credit facility capacity to help finance the acquisition.
Cenovus has fully committed bridge financing in place to manage timing
differences in the funding of the transaction.

Key elements of the financing plan:

/T/

— $3.0 billion bought-deal common share financing (closed April 6, 2017)
— $3.6 billion vendor take-back equity (ConocoPhillips has agreed to take

208 million Cenovus common shares as part of the purchase price)
— US$2.9 billion ($3.9 billion) offering of senior notes at a weighted
average cost of 4.9% (expected to close April 7, 2017)
— $2.7 billion of existing cash on hand
— ~$1.0 billion expected to be drawn from existing committed credit
facility
— $3.6 billion asset-sale bridge loan

/T/

“I’m extremely pleased with the milestones we’ve achieved to date,” said Brian
Ferguson, Cenovus President & Chief Executive Officer. “We’re doing what we
said we’d do. And as we move forward with our plan to complete this
acquisition, we’ll remain focused on preserving our financial resilience,
strengthening our balance sheet and maintaining our investment grade credit
ratings.”

As part of its plan to deleverage and strengthen its balance sheet, Cenovus
has already begun marketing its legacy conventional oil and natural gas assets
at Pelican Lake and Suffield and expects to make additional asset divestitures
as required. Asset sale proceeds and free funds flow are expected to be
applied against Cenovus’s asset-sale bridge loan and draws on its existing
credit facility. Over the long term, Cenovus will continue to target a
debt-to-adjusted earnings before interest, taxes, depreciation and
amortization (EBITDA) ratio of 1.0 to 2.0 times and debt to capitalization of
30% to 40%.

On closing of the acquisition, the company anticipates having approximately $4
billion in remaining liquidity, including $1 billion in cash on hand and $3
billion in unused capacity on its committed credit facility. On a pro forma
basis, assuming the successful closing of the acquisition and including the
anticipated impact of planned asset sales, Cenovus expects to have capacity to
generate 2018 free funds flow of approximately $500 million in a US$50 West
Texas Intermediate (WTI) price environment.

ADVISORY

Forward-Looking Information

This news release contains certain forward-looking statements and other
information (collectively “forward-looking information”) about Cenovus’s
current expectations, estimates and projections, made in light of the
company’s experience and perception of historical trends. Forward-looking
information in this document is identified by words such as “anticipate”,
“expect”, “intend”, “pro forma”, “target”, “will” or similar expressions and
includes suggestions of future outcomes, including statements about: intended
financing of the acquisition; expected asset sales, including anticipated
impacts to Cenovus and expected use of sales proceeds; Cenovus’s long-term
targets for debt to adjusted EBITDA and debt to capitalization ratios; and
Cenovus’s expected 2018 free funds flow capacity. Readers are cautioned not to
place undue reliance on forward-looking information as our actual results may
differ materially from those expressed or implied.

Developing forward-looking information involves reliance on a number of
assumptions and consideration of certain risks and uncertainties, some of
which are specific to Cenovus and others that apply to the industry and the
capital markets generally. The factors or assumptions on which the
forward-looking information is based include: all required financing being
available, and on terms acceptable to Cenovus; completion of the acquisition
on the terms and timing expected; Cenovus’s operations, financial position and
other factors in the event the acquisition is not completed; Cenovus’s ability
to complete planned and potential asset dispositions; application of proceeds
from asset sales and free funds flow to Cenovus’s asset-sale bridge loan and
credit facility draws; forecast crude oil and natural gas prices; and other
risks and uncertainties described from time to time in the company’s filings
with securities regulatory authorities.

The risk factors and uncertainties that could cause the company’s actual
results to differ materially include: Cenovus’s ability to complete the
acquisition, including on the terms and timing expected; Cenovus’s ability to
access various sources of financing, generally, and on terms acceptable to
Cenovus; volatility of and other assumptions regarding oil and natural gas
prices; risks inherent in operation of the company’s business, including
health, safety and environmental risks; risks associated with existing and
potential future lawsuits and regulatory actions; and other risks and
uncertainties described from time to time in the filings we make with
securities regulatory authorities.

Readers are cautioned that the foregoing lists are not exhaustive and are made
as at the date hereof. For a discussion of Cenovus’s material risk factors,
see “Risk Factors” in the company’s Annual Information Form and Form 40-F for
the year ended December 31, 2016, and “Risk Factors” in the prospectus
supplement to Cenovus’s short form base shelf prospectus, dated March 29,
2017, each available on SEDAR at sedar.com and EDGAR at sec.gov.

Non-GAAP Measures
This news release contains references to free funds flow, debt-to-adjusted
EBITDA and debt to capitalization. These measures do not have a standardized
meaning as prescribed by International Financial Reporting Standards (“IFRS”
or “GAAP”) and therefore are considered non-GAAP measures. You should not
consider these measures in isolation or as a substitute for analysis of our
results as reported under IFRS. These measures are defined differently by
different companies in our industry. These measures may not be comparable to
similar measures presented by other issuers. For definitions of these measures
and explanations of how they are used by Cenovus, see “Non-GAAP Measures and
Additional Subtotal” in the prospectus supplement to Cenovus’s short form base
shelf prospectus, dated March 29, 2017, available on SEDAR at sedar.com and
EDGAR at sec.gov.

Cenovus Energy Inc.
Cenovus Energy Inc. is a Canadian integrated oil company. It is committed to
applying fresh, progressive thinking to safely and responsibly unlock energy
resources the world needs. Operations include oil sands projects in northern
Alberta, which use specialized methods to drill and pump the oil to the
surface, and established natural gas and oil production in Alberta and
Saskatchewan. The company also has 50% ownership in two U.S. refineries.
Cenovus shares trade under the symbol CVE, and are listed on the Toronto and
New York stock exchanges.

– END RELEASE – 06/04/2017

For further information:

FOR FURTHER INFORMATION, PLEASE CONTACT:

Cenovus Energy Inc.
www.cenovus.com

COMPANY:
FOR: CENOVUS ENERGY INC.
TSX Symbol: CVE
NYSE Symbol: CVE

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170406CC013

Press Release from Marketwired 1-866-736-3779

Cardinal Energy Ltd. Confirms Monthly Dividend for April

April 6, 2017 by The Canadian Press

FOR: CARDINAL ENERGY LTD.TSX SYMBOL: CJDate issue: April 06, 2017Time in: 5:30 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 6, 2017) – Cardinal Energy Ltd.
(“Cardinal”) (TSX:CJ) confirms that a dividend of $0.035 per common share will
be paid …

ATCO Ltd. Eligible Dividends

April 6, 2017 by The Canadian Press

FOR: ATCO LTD.
TSX SYMBOL: ACO.X
TSX SYMBOL: ACO.Y

Date issue: April 06, 2017
Time in: 5:15 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 6, 2017) – ATCO Ltd. (TSX:ACO.X)
(TSX:ACO.Y)

The Board of Directors of ATCO Ltd. has declared the following quarterly
dividends:

/T/

Shares TSX Stock Dividend Record Date Payment Date
Symbol Per Share ($) (2017) (2017)
—————————————————————————-
Class I Non-Voting ACO.X 0.3275 08-Jun 30-Jun
Class II Voting ACO.Y 0.3275 08-Jun 30-Jun

/T/

These dividends are eligible dividends within the meaning of the Income Tax Act
(Canada).

Forward-Looking Information:

– END RELEASE – 06/04/2017

For further information:
Media & Investor Inquiries:
B.R. (Brian) Bale
Senior Vice President & Chief Financial Officer
403-292-7502

COMPANY:
FOR: ATCO LTD.
TSX SYMBOL: ACO.X
TSX SYMBOL: ACO.Y

Press Release from Marketwired 1-866-736-3779

CU Inc. Eligible Dividends

April 6, 2017 by The Canadian Press

FOR: CU INC.
TSX SYMBOL: CIU.PR.A
TSX SYMBOL: CIU.PR.C

Date issue: April 06, 2017
Time in: 5:14 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 6, 2017) – CU Inc. (TSX:CIU.PR.A)
(TSX:CIU.PR.C)

The Board of Directors of CU Inc. has declared the following Cumulative
Redeemable Preferred Share dividends:

/T/

Shares TSX Stock Dividend Record Date Payment Date
Symbol Per Share ($) (2017) (2017)
—————————————————————————-
Series 1 4.60% CIU.PR.A 0.2875 09-May 01-Jun
Series 4 2.243% CIU.PR.C 0.1401875 09-May 01-Jun

/T/

These dividends are eligible dividends within the meaning of the Income Tax Act
(Canada).

CU Inc. is a wholly-owned subsidiary of Canadian Utilities Limited, an ATCO
Company. CU Inc. is an Alberta-based corporation with approximately 4,100
employees and assets of $15 billion; comprised of rate regulated utility
operations in pipelines, natural gas and electricity transmission and
distribution. More information about CU Inc. can be found on the Canadian
Utilities Limited website at www.canadianutilities.com.

Forward-Looking Information:

– END RELEASE – 06/04/2017

For further information:
Media & Investor Inquiries:
B.R. (Brian) Bale
Senior Vice President & Chief Financial Officer
403-292-7502

COMPANY:
FOR: CU INC.
TSX SYMBOL: CIU.PR.A
TSX SYMBOL: CIU.PR.C

INDUSTRY: Energy and Utilities – Utilities, Energy and Utilities –
Pipelines
RELEASE ID: 20170406CC0092

Press Release from Marketwired 1-866-736-3779

Canadian Utilities Limited Eligible Dividends

April 6, 2017 by The Canadian Press

FOR: CANADIAN UTILITIES LIMITED
TSX SYMBOL: CU
TSX SYMBOL: CU.X

Date issue: April 06, 2017
Time in: 5:12 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 6, 2017) – Canadian Utilities Limited
(TSX:CU) (TSX:CU.X)

The Board of Directors of Canadian Utilities Limited has declared the following
quarterly dividends:

/T/

Shares TSX Stock Dividend Record Date Payment Date
Symbol Per Share ($) (2017) (2017)
—————————————————————————-
Class A non-voting CU 0.3575 09-May 01-Jun
Class B common CU.X 0.3575 09-May 01-Jun
Series Y 4.00% CU.PR.C 0.2500 09-May 01-Jun
Series AA 4.90% CU.PR.D 0.30625 09-May 01-Jun
Series BB 4.90% CU.PR.E 0.30625 09-May 01-Jun
Series CC 4.50% CU.PR.F 0.28125 09-May 01-Jun
Series DD 4.50% CU.PR.G 0.28125 09-May 01-Jun
Series EE 5.25% CU.PR.H 0.328125 09-May 01-Jun
Series FF 4.50% CU.PR.I 0.28125 09-May 01-Jun

/T/

These dividends are eligible dividends within the meaning of the Income Tax Act
(Canada).

Canadian Utilities Limited has a Dividend Reinvestment Plan (DRIP) available to
eligible holders of Class A non-voting shares and Class B common shares.
Eligible shareholders may reinvest the cash dividends paid on their common
shares to purchase new Class A non-voting shares from treasury at a two percent
discount to the volume weighted average price as defined in the DRIP. For more
information visit: www.canadianutilities.com or the CST Trust Company website
at www.canstockta.com.

With approximately 5,400 employees and assets of $19 billion, Canadian
Utilities Limited is an ATCO company. ATCO is a diversified global corporation
delivering service excellence and innovative business solutions in Structures &
Logistics (workforce housing, innovative modular facilities, construction, site
support services, and logistics and operations management); Electricity
(electricity generation, transmission, and distribution); Pipelines & Liquids
(natural gas transmission, distribution and infrastructure development, energy
storage, and industrial water solutions); and Retail Energy (electricity and
natural gas retail sales). More information can be found at
www.canadianutilities.com.

Forward-Looking Information:

– END RELEASE – 06/04/2017

For further information:
Media & Investor Inquiries:
B.R. (Brian) Bale
Senior Vice President & Chief Financial Officer
403-292-7502

COMPANY:
FOR: CANADIAN UTILITIES LIMITED
TSX SYMBOL: CU
TSX SYMBOL: CU.X

INDUSTRY: Energy and Utilities – Utilities, Energy and Utilities –
Pipelines
RELEASE ID: 20170406CC0091

Press Release from Marketwired 1-866-736-3779

Parex Operational Update: Cabrestero Drilling Success Driving Production Growth

April 6, 2017 by The Canadian Press

FOR: PAREX RESOURCES INC.
TSX Symbol: PXT

Date issue: April 06, 2017
Time in: 5:07 PM e

Attention:

CALGARY, AB –(Marketwired – April 06, 2017) – Parex Resources Inc. (“Parex”
or the “Company”) (TSX: PXT), a company headquartered in Calgary, Alberta and
focused on Colombian oil exploration and production, provides an operational
update.

Production: Q1 2017 production was approximately 32,600 barrels of oil
equivalent (“boe/d”) (99% crude oil), an increase of 5% from 31,049 boe/d in
the prior quarter. For Q2 2017, we expect production to average 34,000 boe/d
for an overall increase of approximately 10% for the first half of the year.

Cabrestero (working interest (“WI”) 100%): The Bacano-3 exploration well has
been drilled to a total depth of 12,160 feet to appraise the continuity of the
Guadalupe reservoir, following the exploration success of Bacano-2 and
Jacana-11 on the adjacent Block LLA-34. Bacano-3 is located 1.5 kilometers
south of the Jacana-11 oil well and 1.6 kilometers northwest of the Bacano-2
oil well.

The Bacano-3 well encountered good quality Guadalupe sandstones and the well
was completed and tested with the drilling rig. An Electric Submersible Pump
(“ESP”) was installed in the well and testing commenced on April 3, 2017. As
of April 6, 2017, a total of 5,648 barrels of 17 API oil has been recovered
over a 73 hour period for an average production rate of 1,857 barrels of oil
per day (“bopd”). Bottom hole pressure recorders indicate a producing drawdown
of approximately 35% at the current production rate of 2,070 bopd and a final
watercut of under 1%. After the 7 day short-term test, the well will be shut
in for pressure buildup analysis. The drilling rig was skidded on the same pad
and has spud the Bacano-4 appraisal well with a bottom-hole location
approximately 300 meters southeast of the Bacano-2 location. Bacano-2 was
completed in the upper zone of 3 potential oil zones and was producing at a
stable rate of approximately 580 bopd before being shut-in for pressure
build-up. The Bacano-4 well will be cored and will be used to appraise the
Guadalupe reservoir distribution and quality on the Cabrestero Block.

Playon (WI 50%): The Boranda-1 exploration well, located in the Middle
Magdalena Basin, was drilled to a total depth of 12,173 feet to appraise the
La Paz Formation. The initial completion was undertaken in November 2016 when
the entire La Paz Formation was tested resulting in high water rates with
traces of oil. Due to the inconclusive test results, selective completions
were performed and the well was equipped with a rod pump system. Testing
commenced on March 14, 2017 and over a 20-day period a total of 1,832 barrels
(“bbls”) of 21 API oil has been recovered for an average rate of 94 bopd. The
measured watercut from the well has been decreasing throughout the test from
approximately 30% initially to the current rate of 23%. Fluid level
measurements indicate the well is producing at approximately 90% drawdown.

The testing results from Boranda-1 along with the information from a vertical
seismic profile (“VSP”) of the well will be integrated to determine the
potential location of the Boranda-2 appraisal well which is expected to be
drilled in 2017, subject to partner approval.

Aguas Blancas (WI 50%): Parex continues to advance its assessment of the Aguas
Blancas field. To date in 2017, we have drilled 5 wells of the planned 2017
10-15 well drilling program. A service rig has been mobilized from the
Boranda-1 well to begin completion and testing of the 5 drilled wells on the
AB-3 pad to be followed by completion and testing of the wells on the AB-5
pad. After the wells on both pads have been tested, we expect to commence two
water-flood pilots. Parex expects to begin civil works for two new pads early
in the second half of 2017.

Llanos 34 (WI 55%): Parex continues to delineate the Jacana/Tigana trend.
Jacana-7, Jacana-8 and Jacana Sur-2 have been drilled and will be tested
shortly with a service rig. In addition, an appraisal well Jacana Sur-1 is
currently drilling.

Over the next month, we plan to spud two exploration wells that will evaluate
fault trends that run parallel to the Tigana/Jacana trend. The Sinsonte
exploration prospect is west of Jacana and the Jacamar exploration prospect is
east of the Jacana field.

Upcoming News Events: We look forward to releasing our Q1 2017 unaudited
financial results on May 10, 2017 and holding our Annual General Meeting
(“AGM”) on May 11, 2017.

The AGM will be held at 9:30 a.m. (Calgary Time) at the Conference Centre on
the 4th floor of Eighth Avenue Place East Tower, 525 – 8th Avenue S.W.,
Calgary, AB T2P 1G1.

This news release does not constitute an offer to sell securities, nor is it a
solicitation of an offer to buy securities, in any jurisdiction.

NOT FOR DISTRIBUTION OR FOR DISSEMINATION IN THE UNITED STATES

Advisory on Forward Looking Statements

Certain information regarding Parex set forth in this document contains
forward-looking statements that involve substantial known and unknown risks
and uncertainties. The use of any of the words “plan”, “expect”,
“prospective”, “project”, “intend”, “believe”, “should”, “anticipate”,
“estimate”, “forecast”, “budget” or other similar words, or statements that
certain events or conditions “may” or “will” occur are intended to identify
forward-looking statements. Such statements represent Parex’ internal
projections, estimates or beliefs concerning, among other things, future
growth, results of operations, production, future capital and other
expenditures (including the amount, nature and sources of funding thereof),
competitive advantages, plans for and results of drilling activity, business
prospects and opportunities. These statements are only predictions and actual
events or results may differ materially. Although the Company’s management
believes that the expectations reflected in the forward-looking statements are
reasonable, it cannot guarantee future results, levels of activity,
performance or achievement since such expectations are inherently subject to
significant business, economic, competitive, political and social
uncertainties and contingencies. Many factors could cause Parex’ actual
results to differ materially from those expressed or implied in any
forward-looking statements made by, or on behalf of, Parex.

In particular, forward-looking statements contained in this document include,
but are not limited to, statements with respect to the performance
characteristics of the Company’s oil properties;, forecasted 2017 average
production based on certain oil prices, and anticipated production growth; the
Company’s 2017 capital expenditure budget, including the amount thereof and
the expected allocations of such expenditures to each of maintenance and
development capital, appraisal growth capital and exploration growth capital;
the Company’s anticipated drilling, development, exploration and other growth
plans within its capital expenditure budget, including the Company’s plans to
fulfill certain farm-in and other earning commitments; the Company’s belief
that its capital budget will be fully funded from funds flow from operations
at current Brent strip pricing; Parex’ anticipated debt levels; the Company’s
anticipated cash netbacks; financial and business prospects and financial
outlook; and activities to be undertaken in various areas.

These forward-looking statements are subject to numerous risks and
uncertainties, including but not limited to, the impact of general economic
conditions in Canada and Colombia; prolonged volatility in commodity prices;
industry conditions including changes in laws and regulations including
adoption of new environmental laws and regulations, and changes in how they
are interpreted and enforced in Canada and Colombia; competition; lack of
availability of qualified personnel; the results of exploration and
development drilling and related activities; obtaining required approvals of
regulatory authorities in Canada and Colombia; risks associated with
negotiating with foreign governments as well as country risk associated with
conducting international activities; volatility in market prices for oil;
fluctuations in foreign exchange or interest rates; environmental risks;
changes in income tax laws or changes in tax laws and incentive programs
relating to the oil industry; changes to pipeline capacity; ability to access
sufficient capital from internal and external sources; risks related to the
lawsuit brought in Texas against Parex and certain foreign subsidiaries;
failure of counterparties to perform under contracts; risk that Brent oil
prices are lower than anticipated; risk that Parex’ evaluation of its existing
portfolio of development and exploration opportunities is not consistent with
its expectations; risk that the amounts of operating netbacks, G&A, finance
expenses and tax expenses are higher or lower than anticipated; and other
factors, many of which are beyond the control of the Company. Readers are
cautioned that the foregoing list of factors is not exhaustive. Additional
information on these and other factors that could affect Parex’ operations and
financial results are included in reports on file with Canadian securities
regulatory authorities and may be accessed through the SEDAR website
(www.sedar.com).

Although the forward-looking statements contained in this document are based
upon assumptions which Management believes to be reasonable, the Company
cannot assure investors that actual results will be consistent with these
forward-looking statements. With respect to forward-looking statements
contained in this document, Parex has made assumptions regarding, among other
things: current and anticipated commodity prices and royalty regimes;
availability of skilled labour; timing and amount of capital expenditures;
future exchange rates; the price of oil, including the anticipated Brent oil
price; the impact of increasing competition; conditions in general economic
and financial markets; availability of drilling and related equipment; effects
of regulation by governmental agencies; receipt of partner, regulatory and
community approvals; royalty rates; future operating costs; effects of
regulation by governmental agencies; uninterrupted access to areas of Parex’
operations and infrastructure; recoverability of reserves and future
production rates; the status of litigation; timing of drilling and completion
of wells; on-stream timing of production from successful exploration wells;
operational performance of non-operated producing fields; pipeline capacity;
that Parex will have sufficient cash flow, debt or equity sources or other
financial resources required to fund its capital and operating expenditures
and requirements as needed; that Parex’ conduct and results of operations will
be consistent with its expectations; that Parex will have the ability to
develop its oil and gas properties in the manner currently contemplated; that
Parex’ evaluation of its existing portfolio of development and exploration
opportunities is not consistent with its expectations; anticipated operating
netbacks, G&A, finance expenses and tax expenses for 2017; current or, where
applicable, proposed industry conditions, laws and regulations will continue
in effect or as anticipated as described herein; that the estimates of Parex’
reserves volumes and the assumptions related thereto (including commodity
prices and development costs) are accurate in all material respects; that
Parex will be able to obtain contract extensions or fulfill the contractual
obligations required to retain its rights to explore, develop and exploit any
of its undeveloped properties; and other matters.

Management has included the above summary of assumptions and risks related to
forward-looking information provided in this document in order to provide
shareholders with a more complete perspective on Parex’ current and future
operations and such information may not be appropriate for other purposes.
Parex’ actual results, performance or achievement could differ materially from
those expressed in, or implied by, these forward-looking statements and,
accordingly, no assurance can be given that any of the events anticipated by
the forward-looking statements will transpire or occur, or if any of them do,
what benefits Parex will derive. These forward-looking statements are made as
of the date of this document and Parex disclaims any intent or obligation to
update publicly any forward-looking statements, whether as a result of new
information, future events or results or otherwise, other than as required by
applicable securities laws.

The term “Boe” means a barrel of oil equivalent on the basis of 6 Mcf of
natural gas to 1 barrel of oil (“bbl”). Boe’s may be misleading, particularly
if used in isolation. A boe conversion ratio of 6 Mcf: 1 bbl is based on an
energy equivalency conversion method primarily applicable at the burner tip
and does not represent a value equivalency at the wellhead. Given the value
ratio based on the current price of crude oil as compared to natural gas is
significantly different from the energy equivalency of 6 Mcf:1 bbl, utilizing
a conversion ratio at 6 Mcf:1 bbl may be misleading as an indication of value.

This press release contains certain oil and gas metrics, including cash
netback, which do not have standardized meanings or standard methods of
calculation and therefore such measures may not be comparable to similar
measures used by other companies and should not be used to make comparisons.
Such metrics have been included herein to provide readers with additional
measures to evaluate the Company’s performance; however, such measures are not
reliable indicators of the future performance of the Company and future
performance may not compare to the performance in previous periods and
therefore such metrics should not be unduly relied upon. Cash netback is
calculated as operating netback less G&A, finance expenses and tax expenses.

Neither the TSX nor its Regulation Services Provider (as that term is defined
in the policies of the TSX) accepts responsibility for the adequacy or
accuracy of this release.

– END RELEASE – 06/04/2017

For further information:

For more information, please contact:

Mike Kruchten
Vice-President Corporate Planning and Investor Relations
Parex Resources Inc.
Phone: (403) 517-1733
investor.relations@parexresources.com

COMPANY:
FOR: PAREX RESOURCES INC.
TSX Symbol: PXT

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170406CC009

Press Release from Marketwired 1-866-736-3779

Newfoundland and Labrador budget highlights

April 6, 2017 by The Canadian Press

ST. JOHN’S, N.L. — Highlights from the Newfoundland and Labrador’s new $8.1-billion budget presented Thursday:

— Includes no new taxes or fees and slightly cuts spending by about $300,000.

— Projects an almost $800-million deficit, down from $1.1 billion last year.

— Includes offshore oil royalties of $962 million in 2016-17, almost double what was forecast, thanks to higher prices and productions. Almost $882 million projected in 2017-18.

— Cuts an unpopular gasoline tax by 8.5 cents per litre on June 1 and another four cents per litre on Dec. 1.

— Forecasts an average Brent crude oil price of US$56 per barrel this year.

— $316 million for Memorial University of Newfoundland to help maintain more affordable tuition.

— $120 for inclusive education, including more teachers assistants.

The Canadian Press

Cub Energy Inc. Appoints Chief Operating Officer

April 6, 2017 by The Canadian Press

FOR: CUB ENERGY INC.TSX VENTURE SYMBOL: KUBDate issue: April 06, 2017Time in: 4:00 PM eAttention:
HOUSTON, TEXAS–(Marketwired – April 6, 2017) – Cub Energy Inc. (“Cub” or the
“Company”) (TSX VENTURE:KUB), a Ukraine-focused upstream oil and gas company…

Tanager Energy Announces Grant of Stock Options

April 6, 2017 by The Canadian Press

FOR: TANAGER ENERGY INC.TSX VENTURE SYMBOL: TANDate issue: April 06, 2017Time in: 1:40 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 6, 2017) – Tanager Energy Inc.
(“Tanager” or the “Corporation”) (TSX VENTURE:TAN) announced today that,
subject…

Jaguar Resources Inc. Announces Financing of $38 Million USD

April 6, 2017 by The Canadian Press

FOR: JAGUAR RESOURCES INC.TSX VENTURE SYMBOL: JRIDate issue: April 06, 2017Time in: 10:45 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 6, 2017) –
THIS PRESS RELEASE IS NOT FOR PUBLICATION OR DISSEMINATION IN THE UNITED
STATES, FAILURE TO COMPL…

Leucrotta Exploration Inc. Increases Size of Bought Deal Financing to $80 Million

April 6, 2017 by The Canadian Press

FOR: LEUCROTTA EXPLORATION INC.
TSX VENTURE SYMBOL: LXE

Date issue: April 06, 2017
Time in: 9:44 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 6, 2017) –

NOT FOR DISTRIBUTION TO UNITED STATES NEWS WIRE SERVICES OR FOR DISSEMINATION
IN THE UNITED STATES

Leucrotta Exploration Inc. (“Leucrotta” or the “Company”) (TSX VENTURE:LXE) is
pleased to announce that in connection with its April 5, 2017 announced
Bought-Deal Financing (the “Bought Deal Financing”), Leucrotta has entered into
a revised agreement with the syndicate of Underwriters (the “Underwriters”),
co-led by Haywood Securities Inc. and National Bank Financial Inc., pursuant to
which the Underwriters have agreed to increase the size of the Bought-Deal
Financing. Leucrotta will now issue: (i) 33,333,400 common shares of the
Company (“Common Shares”) at a price of $2.25 per Common Share for gross
proceeds from the offering of Common Shares of approximately $75 million (the
“Common Share Financing”); and (ii) 1,852,000 Common Shares to be issued on a
flow-through basis in respect of Canadian Exploration Expenses (“CEE”) (the
“Flow-Through Shares”) under the Income Tax Act (Canada) at a price of $2.70
per Flow-Through Share for gross proceeds from the offering of Flow-Through
Shares of approximately $5 million (the “Flow-Through Share Financing”). The
aggregate gross proceeds from the increased Common Share Financing and
Flow-Through Share Financing will be approximately $80 million (the
“Financing”).

The Company shall, pursuant to the provisions of the Income Tax Act (Canada),
incur eligible CEE (the “Qualifying Expenditures”) after the closing of the
Financing and prior to December 31, 2018 in the aggregate amount of not less
than the total amount of the gross proceeds raised from the issue and sale of
the Flow-Through Shares. The Company shall renounce the Qualifying Expenditures
so incurred to the purchasers of the Flow-Through Shares effective on or prior
to December 31, 2017.

The Common Shares and Flow-Through Shares to be issued under the Financing will
be distributed by way of a short form prospectus in British Columbia, Alberta,
Saskatchewan, Manitoba, Ontario and New Brunswick. A portion of the Common
Share Financing may be conducted on a private placement basis in the United
States and certain other jurisdictions outside of Canada as the Company and the
Underwriters may agree on a private placement basis. No prospectus will be
required to be filed in any jurisdiction other than the Canadian jurisdictions.

Completion of the Financing is subject to certain conditions including the
receipt of all necessary regulatory approvals, including the approval of the
TSX Venture Exchange and the securities regulatory authorities, as applicable.
The Financing is expected to close on or about April 26, 2017 or such other
date as agreed upon between Leucrotta and the Underwriters, but in any event no
later than May 15, 2017.

ABOUT LEUCROTTA EXPLORATION INC.

Leucrotta Exploration Inc. is a Montney focused producer with lands located in
the Dawson-Sunrise area in northeast British Columbia. Leucrotta’s current
acreage in the area is approximately 100,500 gross (90,200 net) acres or
approximately 157 gross (141 net) sections of Montney land. Current production
is approximately 3,000 boe/d (25% oil & NGLs). Leucrotta’s shares are listed on
the TSX Venture Exchange under the symbol “LXE”.

READER ADVISORIES AND FORWARD-LOOKING INFORMATION

Currency

All dollar figures are Canadian dollars unless otherwise noted.

Forward-Looking Information

More particularly and without limitation, this document contains
forward-looking statements and information relating to the terms of the
Financing including the renunciation of the proceeds from the Flow-Through
Financing and the closing date of the Financing. The forward-looking statements
and information are based on certain key expectations and assumptions made by
the Company, including expectations and assumptions including receipt of all
regulatory approvals for the Financing, prevailing commodity prices and
exchange rates, applicable royalty rates and tax laws, future well production
rates, the performance of existing wells, the success of drilling new wells,
the availability of capital to undertake planned activities and the
availability and cost of labour and services.

Although the Company believes that the expectations reflected in such
forward-looking statements and information are reasonable, it can give no
assurance that such expectations will prove to be correct. Since
forward-looking statements and information address future events and
conditions, by their very nature they involve inherent risks and uncertainties.
Actual results may differ materially from those currently anticipated due to a
number of factors and risks. These include, but are not limited to, the risks
associated with the oil and gas industry in general such as operational risks
in development, exploration and production, delays or changes in plans with
respect to exploration or development projects or capital expenditures, the
uncertainty of estimates and projections relating to production rates, costs
and expenses, commodity price and exchange rate fluctuations, marketing and
transportation, environmental risks, competition, the ability to access
sufficient capital from internal and external sources and changes in tax,
royalty and environmental legislation. The forward-looking statements and
information contained in this document are made as of the date hereof for the
purpose of providing the readers with the Company’s expectations for the coming
year. The forward-looking statements and information may not be appropriate for
other purposes. The Company undertakes no obligation to update publicly or
revise any forward-looking statements or information, whether as a result of
new information, future events or otherwise, unless so required by applicable
securities laws.

This press release is not an offer of the securities for sale in the United
States. The securities have not been registered under the U.S. Securities Act
of 1933, as amended, and may not be offered or sold in the United States absent
registration or an exemption from registration. This press release shall not
constitute an offer to sell or the solicitation of an offer to buy nor shall
there be any sale of the securities in any state in which such offer,
solicitation or sale would be unlawful.

– END RELEASE – 06/04/2017

For further information:
Leucrotta Exploration Inc.
Robert Zakresky
President and Chief Executive Officer
(403) 705-4525
(403) 705-4526 (FAX)
OR
Leucrotta Exploration Inc.
Nolan Chicoine
Vice President, Finance and Chief Financial Officer
(403) 705-4525
(403) 705-4526 (FAX)
www.leucrotta.ca

COMPANY:
FOR: LEUCROTTA EXPLORATION INC.
TSX VENTURE SYMBOL: LXE

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170406CC0045

Press Release from Marketwired 1-866-736-3779

ThreeD Capital Inc. Announces Completion of Private Placement, Appointment of VP Business Development and General Counsel, and Resignation of a Director

April 6, 2017 by The Canadian Press

FOR: THREED CAPITAL INC.CSE SYMBOL: IDKCSE SYMBOL: IDK.CNDate issue: April 06, 2017Time in: 9:37 AM eAttention:
TORONTO, ONTARIO–(Marketwired – April 6, 2017) – ThreeD Capital Inc. (the
“Company”) (CSE:IDK)(CSE:IDK.CN) is pleased to announce that it h…

$10,000 Donation from Just Energy Foundation Secures Breakfast for 10,000 Students in Ontario

April 6, 2017 by The Canadian Press

FOR: JUST ENERGY FOUNDATION
Date issue: April 06, 2017Time in: 9:15 AM eAttention:
TORONTO, ON –(Marketwired – April 06, 2017) – The Just Energy Foundation has
partnered with Breakfast Club of Canada to help alleviate hunger for Ontario
school childr…

Front Range Reports Petroleum Initially-in-Place of 1.8 TCF at Its Pepper, Alberta Montney Property

April 6, 2017 by The Canadian Press

FOR: FRONT RANGE RESOURCES LTD.TSX VENTURE Symbol: FRKDate issue: April 06, 2017Time in: 9:00 AM eAttention:
CALGARY, AB –(Marketwired – April 06, 2017) –
Not for distribution to United States newswire services or for dissemination
in the United State…

Raging River Exploration Inc. Responds to Market Speculation

April 6, 2017 by The Canadian Press

FOR: RAGING RIVER EXPLORATION INC.TSX SYMBOL: RRXDate issue: April 06, 2017Time in: 9:00 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 6, 2017) – Raging River Exploration Inc.
(the “Company” or “Raging River”) (TSX:RRX) is providing the followi…

Pan Orient Energy Corp.: Normal Course Issuer Bid

April 6, 2017 by The Canadian Press

FOR: PAN ORIENT ENERGY CORP.TSX VENTURE SYMBOL: POEDate issue: April 06, 2017Time in: 8:30 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 6, 2017) – Pan Orient Energy Corp. (“Pan
Orient”) (TSX VENTURE:POE) announced today that it intends to cont…

Corridor Announces Update Regarding Anticosti Joint Venture

April 6, 2017 by The Canadian Press

FOR: CORRIDOR RESOURCES INC.
TSX SYMBOL: CDH

Date issue: April 06, 2017
Time in: 8:00 AM e

Attention:

HALIFAX, NOVA SCOTIA–(Marketwired – April 6, 2017) – Corridor Resources Inc.
(TSX:CDH) (“Corridor” or the “Company”) confirms that Corridor, together with
other partners of Anticosti Hydrocarbons L.P., have entered into negotiations
with the Government of Quebec with the goal of terminating the exploration
joint venture project on Anticosti Island. These negotiations have resulted
from a request by Anticosti Hydrocarbons L.P. for the Quebec Government to
clarify its position regarding hydrocarbon exploration and development on
Anticosti as a consequence of the Government’s decision to support an
application for the designation of the island as a UNESCO World Heritage site.

The Anticosti joint venture is a limited partnership formed in 2014 between
Corridor, Ressources Quebec Inc., a subsidiary of Investissement Quebec (an
affiliate of the Government of Quebec), Petrolia Inc. and Saint-Aubin E&P
Quebec Inc. The purpose of the joint venture is to appraise and potentially
develop hydrocarbon resources on Anticosti Island.

No assurance can be given that the negotiations will be successfully concluded.
Corridor does not intend to comment further on the matter until an agreement is
reached or the negotiations end without agreement.

Corridor is a Canadian junior resource company engaged in the exploration for
and development and production of petroleum and natural gas onshore in New
Brunswick and Quebec and offshore in the Gulf of St. Lawrence. Corridor
currently has natural gas production and reserves in the McCully Field near
Sussex, New Brunswick. In addition, Corridor has a shale gas prospect in New
Brunswick, an offshore conventional hydrocarbon prospect in the Gulf of St.
Lawrence and an unconventional hydrocarbon prospect through a 21.67% interest
in Anticosti Hydrocarbons L.P., a joint venture with undeveloped lands on
Anticosti Island, Quebec.

Forward Looking Statements

This press release contains certain forward-looking statements and
forward-looking information (collectively referred to herein as
“forward-looking statements”) within the meaning of Canadian securities laws.
All statements other than statements of historical fact are forward-looking
statements. Forward-looking information typically contains statements with
words such as “anticipate”, “believe”, “plan”, “continuous”, “estimate”,
“expect”, “may”, “will”, “project”, “should”, or similar words suggesting
future outcomes. In particular, this press release contains forward-looking
statements pertaining to: the plans of the Quebec Government, the Anticosti
joint venture partners in respect of the Anticosti joint venture and Anticosti
Island and negotiations regarding the termination of the Anticosti joint
venture.

Undue reliance should not be placed on forward-looking statements, which are
inherently uncertain, are based on estimates and assumptions, and are subject
to known and unknown risks and uncertainties (both general and specific) that
contribute to the possibility that the future events or circumstances
contemplated by the forward-looking statements will not occur. There can be no
assurance that the plans, intentions or expectations upon which forward-looking
statements are based will in fact be realized. Actual results will differ, and
the difference may be material and adverse to Corridor and its shareholders.

Forward-looking statements are based on Corridor’s current beliefs as well as
assumptions made by, and information currently available to, Corridor
concerning the plans of the Quebec Government, business prospects, strategies,
regulatory developments. Although management considers these assumptions to be
reasonable based on information currently available to it, they may prove to be
incorrect. By their very nature, forward-looking statements involve inherent
risks and uncertainties, both general and specific, and risks that
forward-looking statements will not be achieved. These factors may be found
under the heading “Risk Factors” in Corridor’s Annual Information Form for the
year ended December 31, 2016.

The forward-looking statements contained in this press release are made as of
the date hereof and Corridor does not undertake any obligation to update
publicly or to revise any of the included forward-looking statements, except as
required by applicable law. The forward-looking statements contained herein are
expressly qualified by this cautionary statement.

– END RELEASE – 06/04/2017

For further information:
Corridor Resources Inc.
Steve Moran, President
#301, 5475 Spring Garden Road, Halifax, Nova Scotia B3J 3T2
(902) 429-4511
(902) 429-0209 (FAX)
www.corridor.ca

COMPANY:
FOR: CORRIDOR RESOURCES INC.
TSX SYMBOL: CDH

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170406CC0023

Press Release from Marketwired 1-866-736-3779

Verizon Digital Media Services to launch the Verizon Media Xperience Studio, simplifying online video workflows for OTT providers

April 6, 2017 by The Canadian Press

FOR: VERIZON DIGITAL MEDIA SERVICES
Date issue: April 06, 2017Time in: 7:00 AM eAttention:
The all-new content intelligence system from Verizon Digital Media Services
will orchestrate and optimize the OTT workflow while providing key performance,
reven…

Resignation of a Non-Executive Director, Appointment of a Non-Executive Director

April 5, 2017 by The Canadian Press

FOR: SUNSHINE OILSANDS LTD.HKSE SYMBOL: 2012Date issue: April 06, 2017Time in: 12:44 AM eAttention:
HONG KONG, CHINA and CALGARY, ALBERTA–(Marketwired – April 6, 2017) – Sunshine
Oilsands Ltd. (the “Corporation” or “Sunshine”) (HKSE:2012) wishes to an…

Company a no-show in B.C. provincial court on English Bay fuel spill charges

April 6, 2017April 5, 2017 by The Canadian Press

VANCOUVER — A company accused of operating a ship that leaked bunker fuel in Vancouver’s English Bay in April 2015 failed to appear in British Columbia Provincial Court to face charges linked to the spill.

The MV Marathassa and Alassia NewShips Management Inc., a firm based in Greece, were due in court Wednesday on 10 charges, including discharge of a pollutant, but only a lawyer for the ship appeared.

The spill of at least 2,700 litres of bunker fuel in English Bay and the ensuing miscommunications among Canadian authorities and delays in cleanup raised questions about Canada’s preparedness for oil spills.

A lawyer for Alassia previously filed an application for judicial review in Federal Court, alleging Canadian authorities failed to properly serve it with summonses, but its case hit a bump on Tuesday when a judge said the company should instead seek relief in B.C. Supreme Court.

The company has said one summons was delivered to a captain who has no fixed employment with Alassia and who is currently the master of a vessel owned by a different company. However, Crown counsel Jessica Lawn said Wednesday the vessel is operated by Alassia.

Peter Swanson, a lawyer for Alassia, has said the company also does not own the MV Marathassa, but Lawn said outside the courtroom that ownership of the vessel may be determined by the court.

Swanson said in an email he was not in a position to comment on why Alassia did not appear.

The next court date in the case is scheduled for June 1.

In all, six charges have been laid under Canadian shipping legislation, two relate to alleged Fisheries Act violations and single charges are linked to alleged violations of federal environmental laws and the Migratory Bird Act.

The Canadian Press

May pitches London exchange to Saudis for massive Aramco IPO

April 5, 2017 by The Canadian Press

RIYADH, Saudi Arabia — Britain’s prime minister pitched the benefits of the London Stock Exchange during a visit to Saudi Arabia on Wednesday as the kingdom weighs which international market to list shares of oil giant Aramco in what many expect will be the largest public offering in history.

Theresa May made her pitch in the capital, Riyadh, during the second and final day of her visit. Saudi Arabia plans to list less than 5 per cent of the world’s largest oil-producing company on the Saudi exchange and another international exchange, possibly by next year.

May met with King Salman and separately with his son, Deputy Crown Prince Mohammed bin Salman, who is also defence minister and second-in-line to the throne.

May’s Downing Street office said that in a meeting with Saudi Aramco Chairman and Oil Minister Khalid al-Falih she laid out the advantages of doing business in the U.K. The CEO of the London Stock Exchange, Xavier Rolet, was with her for the effort.

Her office said she “set out the sort of depth of expertise that there is in London and the UK in terms of financial services,” as well as “the depth of investment opportunities that there are in the UK.”

The Aramco listing is gearing up to be the biggest flotation ever, with Saudi officials valuing the company at more than $2 trillion.

The flotation is part of a broad effort to raise Saudi Arabia’s profile and boost government revenues after a sharp drop in oil prices hindered its ability to pay for large infrastructure projects and subsidies that citizens have come to rely on.

Saudi Arabia also spends heavily on defence, ranking as the world’s third largest military spender, with billions of dollars in purchases from U.K. manufacturers.

Saudi Arabia is Britain’s largest Mideast trading partner, with British exports of goods and services to the kingdom topping 6.5 billion pounds ($8.1 billion) in 2015.

The U.K.-based Campaign Against Arms Trade says the British government has licensed over 3.3 billion pounds ($4.1 billion) worth of arms to Saudi Arabia since March 2015, when Saudi Arabia began a bombing campaign in neighbouring Yemen.

A Saud-led coalition has been bombing Iranian-allied rebels known as Houthis in Yemen for two years, but has not been able to seize the capital and other territories under Houthi control.

The U.K. provides the coalition with technical support, precision-guided bombs and intelligence sharing.

Rights groups have called on the U.S., Britain and France to halt the sale of weapons used in the war to Saudi Arabia. The conflict has killed at least 4,770 civilians and wounded more than 8,200 according to the U.N. human rights office.

May discussed the humanitarian crisis in Yemen during her meeting with the Saudi king. Around 21 million people, roughly 82 per cent of the population, are in urgent need of humanitarian assistance.

In a gesture to cement the bilateral relationship, the monarch awarded her the Order of King Abdulaziz, named after the founder of Saudi Arabia, Salman’s father. Previous leaders who have received the award include her predecessor, David Cameron, and U.S. President Barack Obama.

___

Batrawy reported from Dubai, United Arab Emirates.

Abdullah Al-Shihri And Aya Batrawy, The Associated Press

Spanish energy giant joins list of companies subletting downtown Calgary offices

April 5, 2017 by The Canadian Press

CALGARY — Spanish oil and gas giant Repsol SA is looking to sublet some of its downtown Calgary office space, adding to a market already swollen by energy industry cutbacks and layoffs.

Repsol’s Canadian branch has vacated eight of its 22 floors in the 52-floor Bankers Hall West over the past year and is now seeking tenants to take over its leases, said spokeswoman Berta Gomez in an email.

She said the space was originally leased by Calgary-based Talisman Energy, which was purchased by Madrid-based Repsol in May 2015 for about US$8.3 billion in cash plus debt of US$4.7 billion.

Talisman had leased extra space for growth that didn’t occur, Gomez said, adding that Repsol has fewer employees in the building now than when it bought Talisman because of relocations and staff cuts.

“We have arranged employees in a higher density manner in order to free up space for sublease and to promote teamwork,” she said in an email.

She wouldn’t say how many employees work in the building now. Repsol Canada said a year ago it would cut 10 to 15 per cent of its former Talisman staff without saying how many people that represented.

In a disclosure document filed in February, the company said it had 1,173 workers in North America as of Dec. 31, 2016. That’s down more than 400 from Talisman’s 1,576 North American staff count at the end of 2014.

Industry watcher PetroLMI estimates 52,500 Canadian energy industry jobs were lost in 2015 and 2016, a reduction of about 25 per cent from the industry peak of over 226,000 in 2014.

The list of oil and gas companies with space to sublet in Calgary includes Cenovus Energy, Husky Energy, Encana, Brion Energy, Canadian Natural Resources, Progress Energy, Shell, Suncor Energy, Enerplus and MEG Energy, according to the Calgary office of real estate firm CBRE.

In a report Tuesday, Barclay Street Real Estate said that Calgary’s overall downtown office vacancy rate increased by 0.7 of a percentage point to 24.2 per cent in the first three months of the year.

That represents a total of about 10 million square feet of space available for lease out of an inventory of just over 41 million square feet.

It added that an additional half million square feet of new office space is expected to be added to the market over the summer and another one million will become available in seven to 18 months.

“This ‘shadow vacancy’ brings the vacancy rate in Calgary’s downtown to an estimated 26.6 per cent,” the report notes.

Some of the new space will be provided by Brookfield Place, whose 56-floor east tower, expected by owners to be the tallest building in Western Canada, is to be ready for occupancy late this year.

Cenovus spokesman Reg Curren said the company was expected to move staff there upon opening, but recently negotiated with the owner to delay the move until early 2019 because its need for office space has declined due to lower staffing levels.

Follow @HealingSlowly on Twitter.

Dan Healing, The Canadian Press

Canadian Utilities Limited to Release First Quarter Results Wednesday, April 26, 2017

April 5, 2017 by The Canadian Press

FOR: CANADIAN UTILITIES LIMITED
TSX SYMBOL: CU
TSX SYMBOL: CU.X

Date issue: April 05, 2017
Time in: 5:05 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 5, 2017) – Canadian Utilities Limited
(TSX:CU) (TSX:CU.X) Canadian Utilities Limited will release its financial
results for the quarter ended March 31, 2017 on Wednesday, April 26, 2017. The
news release will be distributed via www.marketwired.com and the results,
including Financial Statements and Management’s Discussion & Analysis, will be
posted on www.canadianutilities.com.

Forward-Looking Information:

– END RELEASE – 05/04/2017

For further information:
Media & Investor Inquiries:
B.R. (Brian) Bale
Senior Vice President & Chief Financial Officer
403-292-7502

COMPANY:
FOR: CANADIAN UTILITIES LIMITED
TSX SYMBOL: CU
TSX SYMBOL: CU.X

INDUSTRY: Energy and Utilities – Utilities, Energy and Utilities –
Pipelines
RELEASE ID: 20170405CC0082

Press Release from Marketwired 1-866-736-3779

Leucrotta Exploration Inc. Announces a Strategic Montney Land Acquisition and a $50 Million Bought Deal Financing

April 5, 2017 by The Canadian Press

FOR: LEUCROTTA EXPLORATION INC.
TSX VENTURE SYMBOL: LXE

Date issue: April 05, 2017
Time in: 4:08 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 5, 2017) –

NOT FOR DISTRIBUTION TO UNITED STATES NEWS WIRE SERVICES OR FOR DISSEMINATION
IN THE UNITED STATES

Leucrotta Exploration Inc. (“Leucrotta” or the “Company”) (TSX VENTURE:LXE) is
pleased to announce that it has entered into agreements with public Alberta
based oil and gas companies to acquire 18.5 net sections of land located within
Leucrotta’s higher confidence mapping area(1) encompassing 116 gross (105 net)
sections of the Lower Montney Turbidite Light Oil Resource Play (the “Lands”)
(see detailed Press Release dated April 4, 2017) for $36 million (the
“Acquisition”). The Lands are comprised of 18 sections of 100% working interest
Crown lands and one 50% working interest section (Leucrotta currently being the
other 50% working interest partner). The Lands increase Leucrotta’s gross
acreage land base within Leucrotta’s higher confidence mapping area(1) by
approximately 18%.

The Lands are adjacent and intertwined with Leucrotta’s lands and gathering
system and are offsetting or in immediate vicinity of several significant Lower
and Upper Montney wells, including Leucrotta’s recently announced 8-22 Lower
Montney Turbidite Light Oil well as well as Leucrotta’s original Doe
development block that has been drilled for both liquids-rich gas in the Upper
and Lower Montney.

Leucrotta’s Lower Montney Light Oil wells, using type-well curve data used by
GLJ Petroleum Consultants Ltd. (“GLJ”) in preparing the GLJ’s reserves report
in respect of the Company’s reserves effective as at December 31, 2016, have an
average recovery of 669 mboes and generate an average NPV10 (as defined under
“Oil and Gas Metrics” under “Reader Advisories and Forward-Looking
Information”) of $7.1 million using GLJs January 2017 price forecast.(2) In
addition, based on the aforementioned GLJ type-well curve data and GLJ’s
January 2017 price forecast, Leucrotta’s Lower Montney Liquids-rich Gas wells
have an average recovery of 1,055 mboes and an average NPV10 of $8.7 million.(2)

Leucrotta has mapped 16 of the 18.5 sections in the Light Oil window and 2.5
sections in the liquids-rich gas window. This represents a possible increase in
drilling inventory of 128 Lower Montney Light Oil Wells and 10 Lower Montney
Liquids-rich Gas Wells using 8 wells per section for oil and 4 wells per
section for gas. The Acquisition will increase Leucrotta’s total Lower Montney
Oil drilling locations to 768 (20% increase) and Lower Montney Liquids-rich Gas
locations to 110 (10% increase).(3)

The Acquisition will be funded with a portion of the proceeds of a $50 million
bought deal equity financing (the “Financing”) co-led by Haywood Securities
Inc. and National Bank Financial Inc., details of which are provided below
under the heading “Bought Deal Financing” in this press release.

ACQUISITION OVERVIEW & STRATEGIC RATIONALE

Leucrotta has signed definitive agreements to acquire 18.5 net sections of
Montney Land in its Doe/Mica Core area for a total purchase price of $36
million. The Lands have the following characteristics and/or anticipated
benefits to the Company:

/T/

— Located directly adjacent Leucrotta’s Lower Montney Turbidite Resource

play as more fully described in Leucrotta’s press release dated April 4,
2017, a copy of which is available under Leucrotta’s SEDAR profile at
www.sedar.com.
— Leucrotta has drilled wells directly adjacent to a portion of the Lands
and believes the Company could book additional reserves on a portion of
the Lands. Montney competitors have also drilled successful wells in the
immediate vicinity of the Lands for both Upper and Lower Montney.
— Leucrotta’s 100% owned and operated pipeline infrastructure has been
constructed through parts of the Lands creating easier access and
improved half-cycle economics on the Lands.
— Majority of the Lands are located in the Oil Window of the Lower Montney
Turbidite Play as mapped internally by the Company.
— Ownership of Lands will eliminate drilling offset boundaries thereby
improving the effectiveness of the well spacing for both current and
acquired Lands.
— Lands materially add to the resource base captured by Leucrotta in its
core Doe/Mica area.

/T/

BOUGHT DEAL FINANCING

In connection with the Acquisition, Leucrotta has entered into an agreement
with a syndicate of underwriters, co-led by Haywood Securities Inc. and
National Bank Financial Inc. (collectively, the “Underwriters”), pursuant to
which the Underwriters have agreed to purchase for resale to the public, on a
bought deal basis: (i) 20,000,000 common shares of the Company (“Common
Shares”) at a price of $2.25 per Common Share for gross proceeds from the
offering of Common Shares of $45 million (the “Common Share Financing”); and
(ii) 1,852,000 Common Shares to be issued on a flow-through basis in respect of
Canadian Exploration Expenses (“CEE”) (the “Flow-Through Shares”) under the
Income Tax Act (Canada) at a price of $2.70 per Flow-Through Share for gross
proceeds from the offering of Flow-Through Shares of approximately $5 million
(the “Flow-Through Share Financing”). The aggregate gross proceeds from the
Common Share Financing and Flow-Through Share Financing will be approximately
$50 million (the “Financing”).

The Common Shares and Flow-Through Shares to be issued under the Financing will
be distributed by way of a short form prospectus in British Columbia, Alberta,
Saskatchewan, Manitoba, Ontario and New Brunswick. A portion of the Common
Share Financing may be conducted on a private placement basis in the United
States via Rule 144A to Qualified Institutional Buyers only under the U.S.
Securities Act of 1933, as amended and certain other jurisdictions outside of
Canada as the Company and the Underwriters may agree on a private placement
basis. No prospectus will be required to be filed in any jurisdiction other
than the Canadian jurisdictions.

Completion of the Acquisition and the Financing are subject to certain
conditions including the receipt of all necessary regulatory approvals,
including the approval of the TSX Venture Exchange and the securities
regulatory authorities, as applicable. The Financing is expected to close on or
about April 26, 2017 or such other date as agreed upon between Leucrotta and
the Underwriters, but in any event no later than May 15, 2017. The Acquisition
is expected to close on or about May 31, 2017.

ADVISOR

National Bank Financial Inc. acted as strategic advisor to Leucrotta with
respect to the Acquisition.

ABOUT LEUCROTTA EXPLORATION INC.

READER ADVISORIES AND FORWARD-LOOKING INFORMATION

NOTES:

(1) Leucrotta’s higher confidence mapping area is based on internal estimates
by management of the Company, estimated based on data collected by the Company
from its coring data collected and drilling programs conducted since inception
of the Company.

(2) Recovery is equivalent to EUR – Estimated Ultimate Recovery which is
defined as “those quantities of petroleum which are estimated, on a given date,
to be potentially recoverable from an accumulation, plus those quantities
already produced therefrom.”

The well economics presented in this press release are an internal estimate
prepared by a Qualified Reserves Evaluator (“QRE”) as defined in NI 51-101 (as
defined herein) and are based on an average of the proved plus probable type
curves used by GLJ for booked undeveloped horizontal wells in the Lower Montney
formation as per the year-end 2016 corporate reserves evaluation effective
December 31, 2016 prepared by GLJ in compliance with NI 51-101 and the COGE
Handbook. The curves represent an internal “best-estimate” expectation.

Type Curves – This Press Release contains references to type well, or “type
curve”, production and economics, which are derived, at least in part, from
available information respecting the well performance of other companies and,
as such, may be considered “analogous information” as defined in NI 51-101.
Production type curves are based on a methodology of analog, empirical and
theoretical assessments and workflow with consideration of the specific asset,
and as depicted in this presentation, is representative of The Company’s
current program, including relative to current performance. Some of this data
may not have been prepared by qualified reserves evaluators, may have been
prepared based on internal estimates, and the preparation of any estimates may
not be in strict accordance with COGEH. Estimates by engineering and geo-
technical practitioners may vary and the differences may be significant. The
Company believes that the provision of this analogous information is relevant
to the Company’s oil and gas activities, given its acreage position and
operations (either ongoing or planned) in the areas in question, and such
information has been updated as of the date hereof unless otherwise specified.

(3) Potential Drilling Locations – This press release discloses drilling
locations in four categories: (i) proved undeveloped locations; (ii) probable
undeveloped locations; (iii) unbooked locations; and (iv) an aggregate total of
(i), (ii) and (iii). Of the 768 total potential/possible Lower Montney oil
locations referenced in this press release, only the following have been
assigned reserves at December 31, 2016 as independently evaluated by GLJ, in
accordance with National Instrument 51-101 (“NI 51-101”):

/T/

— 1 Proved Undeveloped
— 2 Probable Undeveloped

/T/

The remaining 765 potential/possible locations are unbooked.

All of the additional 128 additional Lower Montney oil locations referenced in
this press release are unbooked locations and are included in the above total
of 768 locations.

Of the 110 total potential/possible Lower Montney liquids-rich gas locations
referenced in this press release, only the following have been assigned
reserves at December 31, 2016 as independently evaluated by GLJ, in accordance
with National Instrument 51-101 (“NI 51-101”):

/T/

— 4 Proved Undeveloped
— 6 Probable Undeveloped

/T/

The remaining 100 potential/possible locations are unbooked.

All of the additional 10 additional Lower Montney Liquids-rich gas locations
referenced in this press release are unbooked locations and are included in the
above total of 110 locations.

Unbooked locations are based on the Company’s prospective acreage and internal
estimates as to the number of wells that can be drilled per section. Unbooked
locations do not have attributed reserves or resources (including contingent
and prospective). Unbooked locations have been identified by management as an
estimation of the Company’s multi-year drilling activities based on evaluation
of applicable geologic, seismic, engineering, production and reserves
information. There is no certainty that the Company will drill all unbooked
drilling locations and if drilled there is no certainty that such locations
will result in additional oil and gas reserves, resources or production. The
drilling locations on which the Company will actually drill wells, including
the number and timing thereof is ultimately dependent upon the availability of
funding, regulatory approvals, seasonal restrictions, oil and natural gas
prices, costs, actual drilling results, additional reservoir information that
is obtained and other factors. While certain of the unbooked drilling locations
have been de-risked by drilling existing wells in relative close proximity to
such unbooked drilling locations, the majority of other unbooked drilling
locations are farther away from existing wells where management has less
information about the characteristics of the reservoir and therefore there is
more uncertainty whether wells will be drilled in such locations and if drilled
there is more uncertainty that such wells will result in additional oil and gas
reserves, resources or production.

Currency

All dollar figures are Canadian dollars unless otherwise noted.

Oil and Gas Metrics

This new release contains metrics commonly used in the oil and gas industry,
such as “NPV”, “BOE”, and “Half-cycle economics”. These terms do not have
standardized meanings or standardized methods of calculation and therefore may
not be comparable to similar measures presented by other companies. Readers are
cautioned that the information provided by these metrics, or that can be
derived from the metrics presented in this presentation should not be unduly
relied upon. The following oil and gas metrics have the following meanings as
used in this press release:

NPV10 – The term NPV10 as used in this press release refers to the Net Present
Value of the proved and probable reserves discounted at 10% which is the
present value of future cash flows minus the initial capital, discounted at 10%.

Boe – Barrel of Oil Equivalent. All boe conversions in the report are derived
by converting gas to oil at the ratio of six thousand cubic feet of natural gas
to one barrel of oil equivalent. Boe may be misleading, particularly if used in
isolation. A boe conversion rate of 1 Boe: 6 Mcf is based on an energy
equivalency conversion method primarily applicable at the burner tip and does
not represent a value equivalency at the wellhead. Readers are cautioned that
Boe may be misleading, particularly if used in isolation.

Half Cycle Economics – The term half-cycle economics as used in this press
release refers to economics of a project including drilling, completing and
tie-in of wells and excludes land, seismic and initial facility costs.

Forward-Looking Information

More particularly and without limitation, this document contains
forward-looking statements and information relating to the terms of the
Financing, anticipated use of proceeds under the Financing, terms of the
Acquisition and anticipated benefits of the Acquisition to the Company. The
forward-looking statements and information are based on certain key
expectations and assumptions made by the Company, including expectations and
assumptions relating to prevailing commodity prices and exchange rates,
applicable royalty rates and tax laws, future well production rates, the
performance of existing wells, the success of drilling new wells, the
availability of capital to undertake planned activities and the availability
and cost of labour and services.

Although the Company believes that the expectations reflected in such
forward-looking statements and information are reasonable, it can give no
assurance that such expectations will prove to be correct. Since
forward-looking statements and information address future events and
conditions, by their very nature they involve inherent risks and uncertainties.
Actual results may differ materially from those currently anticipated due to a
number of factors and risks. These include, but are not limited to, the risks
associated with the oil and gas industry in general such as operational risks
in development, exploration and production, delays or changes in plans with
respect to exploration or development projects or capital expenditures, the
uncertainty of estimates and projections relating to production rates, costs
and expenses, commodity price and exchange rate fluctuations, marketing and
transportation, environmental risks, competition, the ability to access
sufficient capital from internal and external sources and changes in tax,
royalty and environmental legislation. The forward-looking statements and
information contained in this document are made as of the date hereof for the
purpose of providing the readers with the Company’s expectations for the coming
year. The forward-looking statements and information may not be appropriate for
other purposes. The Company undertakes no obligation to update publicly or
revise any forward-looking statements or information, whether as a result of
new information, future events or otherwise, unless so required by applicable
securities laws.

– END RELEASE – 05/04/2017

COMPANY:
FOR: LEUCROTTA EXPLORATION INC.
TSX VENTURE SYMBOL: LXE

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170405CC0072

Press Release from Marketwired 1-866-736-3779

Vantage Drilling International Announces Acquisition

April 5, 2017 by The Canadian Press

FOR: VANTAGE DRILLING INTERNATIONAL

Date issue: April 05, 2017
Time in: 4:00 PM e

Attention:

HOUSTON, TX–(Marketwired – April 05, 2017) – Vantage Drilling International
(“Vantage”), announced today that its subsidiary, Vantage Drilling Africa, has
acquired the Hercules 260, a Marathon LeTourneau Class jack-up drilling unit,
from Hercules International Drilling, Ltd., a subsidiary of Hercules Offshore,
Inc., for an undisclosed amount and has renamed the rig the Vantage 260. As
part of the acquisition, Vantage Drilling Africa acquired a multi-year drilling
contract with ENI Congo.

Vantage is reactivating the Sapphire Driller, a Baker Marine Pacific Class 375
jack-up rig currently warm-stacked offshore of the Republic of Congo, and later
this year will substitute it for the Vantage 260.

Ihab Toma, Vantage’s Chief Executive Officer, commented, “We are delighted to
have completed this transaction and are happy to welcome the 260 team to
Vantage. We look forward to continuing the excellent operations for ENI Congo.”

Vantage Drilling International, a Cayman Islands exempted company, is an
offshore drilling contractor, with a fleet of three ultra-deepwater drillships,
four premium jackup drilling rigs and one standard jack-up drilling rig.
Vantage’s primary business is to contract drilling units, related equipment and
work crews primarily on a dayrate basis to drill oil and natural gas wells
globally for major, national and large independent oil and natural gas
companies. Vantage also provides construction supervision services and
preservation management services for, and will operate and manage, drilling
units owned by others.

The information above includes forward-looking statements within the meaning of
the Securities Act of 1933 and the Securities Exchange Act of 1934. These
forward-looking statements are subject to certain risks, uncertainties and
assumptions identified above or as disclosed from time to time in the company’s
filings that it may be required to make, or may otherwise voluntarily make,
with the Securities and Exchange Commission. As a result of these factors,
actual results may differ materially from those indicated or implied by such
forward-looking statements. Vantage disclaims any intention or obligation to
update publicly or revise such statements, whether as a result of new
information, future events or otherwise.

– END RELEASE – 05/04/2017

For further information:
Public & Investor Relations Contact:
OR
Thomas J. Cimino
Chief Financial Officer
Vantage Drilling International
(281) 404-4700

COMPANY:
FOR: VANTAGE DRILLING INTERNATIONAL

INDUSTRY: Energy and Utilities – Oil and Gas , Energy and Utilities
– Pipelines
RELEASE ID: 20170405CC0070

Press Release from Marketwired 1-866-736-3779

Petrolia’s comment on the Anticosti negotiation

April 5, 2017 by The Canadian Press

FOR: PETROLIA INC.
TSX VENTURE SYMBOL: PEA

Date issue: April 05, 2017
Time in: 3:55 PM e

Attention:

QUEBEC CITY, QUEBEC–(Marketwired – April 5, 2017) – Petrolia Inc. (TSX
VENTURE:PEA) confirms that, in response to a request for clarification from
Hydrocarbures Anticosti (HASEC) concerning the status of the Anticosti project
in light of the request that the island be recognized as a UNESCO world
heritage site, the Gouvernement du Quebec has begun negotiations with the
company and its partners in HASEC with the goal of ending oil and gas
exploration on Anticosti Island.

Petrolia would like to point out that the government of Quebec determined the
value of this project at $200M when the deal was announced in February 2014 and
that, in the economic survey by the Ministere des Finances prepared within the
framework of the Evaluations Environnementales Strategiques (EES), the
government anticipated major economic gains. It is also relevant to note that
Petrolia holds 21.7% of HASEC and that it is also the contract operator on the
project. Nevertheless, in the event that the government is determined to put an
end to this project, Petrolia is open to negotiating a fair settlement.

“We are still fully convinced, even more than in 2014, of the potential and the
relevance of the Anticosti project for Quebec and its society. However, we
enter this negotiation in good faith. In our view, Anticosti remains and will
always remain a major economic project that could potentially generate
important spinoffs for Quebec” said Martin Belanger, Interim President and
Chief Executive Officer of Petrolia.

Finally, in the event that there is no settlement, we expect the government to
respect the agreements signed in good faith and allow the HASEC to carry out
the planned works that were mandated in the signed agreements.

About Petrolia

Petrolia is a junior oil and gas exploration company which owns interests in
oil and gas licences covering 16,000 km2 (4 million acres), which represents
almost 23% of the Quebec Territory under lease. The closing of a partnership on
Anticosti Island has led to the creation of Anticosti Hydrocarbons L.P., a
limited partnership in which Petrolia holds a 21.7% interest. In order to carry
out the project’s operations, Petrolia Anticosti Inc., a subsidiary of
Petrolia, was designated project operator. Petrolia is a Quebec company whose
objective is to develop oil from here, by the people here, for here. Petrolia
has 108,399,683 shares issued and outstanding.

Disclaimer

Certain statements made herein may constitute forward-looking statements. These
statements relate to future events or the future economic performance of
Petrolia and carry known and unknown risks, uncertainties and other factors
that may appreciably affect their results, economic performance or
accomplishments when considered in light of the content or implications or
statements made by Petrolia. Actual events or results could be significantly
different. Accordingly, investors should not place undue reliance on
forward-looking statements. Petrolia disclaims any intention or obligation to
update these forward-looking statements.

– END RELEASE – 05/04/2017

For further information:
Petrolia Inc.
Martin Belanger, P. Eng.
Interim President & Chief Executive Officer
418 657-1966
mbelanger@petrolia-inc.com
www.petrolia-inc.com

COMPANY:
FOR: PETROLIA INC.
TSX VENTURE SYMBOL: PEA

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170405CC0066

Press Release from Marketwired 1-866-736-3779

Imex Systems Inc.: Business Update

April 5, 2017 by The Canadian Press

FOR: IMEX SYSTEMS INC.TSX VENTURE SYMBOL: IMEXDate issue: April 05, 2017Time in: 1:11 PM eAttention:
TORONTO, ONTARIO–(Marketwired – April 5, 2017) – Imex Systems Inc. (“Imex” or
the “Company”) (TSX VENTURE:IMEX), a software solution provider to Gover…

The U.S. Rig Count Is An Over-Rated Indicator of Future Oil Prices: Read Why HERE – David Yager – Yager Management

June 28, 2017April 5, 2017 by EnergyNow Media

David Yager – Yager Management Ltd. Oilfield Service Management Consulting – Oil & Gas Writer – Energy Policy Analyst April 4, 2017 The Baker Hughes North American Rotary Rig Count wallowed in relative obscurity among the world’s business writers for decades. The Hughes in Baker Hughes is the original Hughes Tool … Read more

Savanna Energy Services Corp. and Total Energy Services Inc. Announce Reconstituted Savanna Board of Directors

April 5, 2017 by The Canadian Press

FOR: TOTAL ENERGY SERVICES INC.TSX SYMBOL: TOTAND SAVANNA ENERGY SERVICES CORP.TSX SYMBOL: SVYDate issue: April 05, 2017Time in: 12:15 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 5, 2017) – Savanna Energy Services Corp.
(“Savanna”) (TSX:SVY) …

Alectra Utilities recognized as ‘Thought Leader’ for pricing pilot

April 5, 2017 by The Canadian Press

Gibsons to Release First Quarter 2017 Results and Hold Annual General Meeting

April 5, 2017 by The Canadian Press

FOR: GIBSON ENERGY INC.
TSX SYMBOL: GEI

Date issue: April 05, 2017
Time in: 8:00 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 5, 2017) – Gibson Energy Inc. (“Gibsons”
or the “Company”) (TSX:GEI) announced today that it expects to release its
first quarter results for the period ending March 31, 2017 on Monday, May 8,
following market close. A conference call has also been scheduled for 7:00 a.m.
MT (9:00 a.m. ET) on Tuesday, May 9, 2017 for interested analysts, investors,
and media representatives. The conference call dial-in numbers are:

/T/

— 416-340-2217 / 866-696-5910
— Participant Pass Code: 5924396

/T/

Shortly after the call, an audio archive will be posted on the Investors/News
section at www.gibsons.com. The call will also be recorded and available for
playback 60 minutes after the meeting end time, until August 1, 2017, using the
following dial-in numbers:

/T/

— 905-694-9451 / 800-408-3053
— Participant Pass Code: 8719230

/T/

The Company also wishes to announce that its Annual General Meeting (the “AGM”)
will be held on Tuesday, May 9, 2017 at 10:00 a.m. MT (12:00 p.m. ET) in the
Brittannia and Belaire Room of The Westin Calgary, 320 – 4th Avenue S.W.,
Calgary, Alberta. The AGM will be broadcast live via webcast. The webcast link
will be available on Gibsons’ website at gibsons.com under Investor
Relations/Presentations, Webcasts and Events. Additionally, shortly after the
AGM, an audio archive of the webcast will be made accessible on Gibsons’
website for 90 days.

About Gibsons

Gibsons is a Canadian-based midstream energy company with operations in most of
the key hydrocarbon-rich basins in North America. For over 60 years, Gibsons
has delivered integrated midstream solutions to customers in the oil and gas
industry. With headquarters in Calgary, Alberta, the Company’s North American
operations include the storage, blending, processing, transportation, marketing
and distribution of crude oil, liquids and refined products. The Company also
provides oilfield waste and water management services.

Gibson Energy Inc. shares trade under the symbol GEI and are listed on the
Toronto Stock Exchange. For more information, visit www.gibsons.com.

– END RELEASE – 05/04/2017

For further information:
Tammi Price
Vice President Finance & Corporate Affairs
(403) 206-4212
tprice@gibsons.com

COMPANY:
FOR: GIBSON ENERGY INC.
TSX SYMBOL: GEI

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170405CC0012

Press Release from Marketwired 1-866-736-3779

Sunshine Oilsands Ltd.: Issue of Shares Under General Mandate for Settlement of Indebtness

April 5, 2017 by The Canadian Press

FOR: SUNSHINE OILSANDS LTD.HKSE SYMBOL: 2012Date issue: April 05, 2017Time in: 7:30 AM eAttention:
HONG KONG, CHINA and CALGARY, ALBERTA–(Marketwired – April 5, 2017) – The
Board of Directors (the “Board”) of Sunshine Oilsands Ltd. (the “Corporation”
…

Employment Equity: Do You Ask Job Applicants If They Are Part of The Four ‘Designated Groups’? Here's What You Should Know! – Wendy Ferguson – BHRLR, CPHR

June 28, 2017April 4, 2017 by EnergyNow Media

By Wendy Ferguson – BHRLR, CPHR – Ferguson HR Consulting I was recently asked by a business leader if most Alberta energy sector companies are asking online job applicants to self-identify as one of the four “designated groups”. These would include: women, those with a disability, aboriginal people and visible … Read more

Company charged in English Bay fuel spill must challenge summons in B.C. court

April 4, 2017 by The Canadian Press

VANCOUVER — A Federal Court judge has rejected an application for judicial review filed by a Greece-based company facing charges in a 2015 fuel spill in Vancouver’s English Bay, saying it must make its case in British Columbia Supreme Court.

The MV Marathassa and Alassia NewShips Management Inc. each face 10 charges, including discharge of a pollutant and failure to implement an oil pollution emergency plan and are scheduled to appear in B.C. Provincial Court on Wednesday.

Alassia had asked the Federal Court to set aside summonses and declare that attempts to serve the documents by the Public Prosecution Service of Canada and the Attorney General were invalid.

Alassia Lawyer Peter Swanson said Tuesday a summons for the Marathassa has been accepted, but orders to appear addressed to his client were wrongfully served to a Canadian insurance adjuster and a ship captain who didn’t work for the company.

Lisa Laird, lawyer for Canada’s Attorney General, argued the question of whether the service was valid should be decided by a B.C. court and Federal Court Justice Glennys McVeigh agreed.

Swanson also clarified that Alassia does not own the Marathassa — the company is described on its website as a ship management company that offers services to owners of vessels.

The Canadian Press

National Energy Board outsources whistleblower hotline to private company

April 4, 2017 by The Canadian Press

CALGARY — The National Energy Board is outsourcing its whistleblower hotline to a private company after a consultant criticized flaws in its system to field complaints from tipsters who want to remain anonymous.

The federal agency says it has signed an agreement with Toronto-based ClearView Connects, a confidential reporting service, which is now accepting anonymous calls, letters and emails on the NEB’s behalf.

In a report commissioned by the NEB early last year, a consultant warned the system could put staff in direct verbal contact with tipsters and could create an electronic trail identifying tipsters if NEB telephone records were made public.

It cautioned that staff could wind up directly involved in related followup action or be able to identify the tipster and subsequently have to disclose that information under oath during a hearing.

The report prompted a revamp of the system with new safeguards in April last year, but a decision to outsource the operation was made after further review.

NEB spokeswoman Erin Dottor says the NEB reviewed its practices because the number of whistleblower reports have gradually increased, rising from six in 2012 to nine in 2015 and 10 in 2016.

She says disclosures made to ClearView that could reveal the identity of a tipster will be isolated from other NEB databases to protect the information.

She says the cost for ClearView’s service is $27,000 for one year, with an option for years two and three for $24,000.

The Canadian Press

Swiss watchdog: Probes of money laundering jump in 2016

April 4, 2017 by The Canadian Press

BERN, Switzerland — Switzerland’s financial markets watchdog says it investigated 22 breaches of money laundering requirements last year, from nine in 2015, as the Alpine country seeks to combat the growing risk of corruption linked to assets from around the world.

The authority, FINMA, said Tuesday that “serious shortcomings” came to light in 2016, including major cases involving the Malaysian sovereign wealth fund, 1MDB, and Brazilian oil company Petrobras. At year-end, FINMA had classified 21 unspecified banks as “high risk” — meaning their activities are under enhanced surveillance.

“Over the past four years, FINMA has taken enforcement action against supervised institutions in about 40 cases for breaches of anti-money laundering regulations, but the scale of the recent misconduct is unprecedented,” FINMA said in a statement with the release of its annual report.

“Several Swiss financial institutions have been caught up in major international corruption cases, not least those involving the Malaysian sovereign wealth fund 1MDB and Brazilian oil company Petrobras,” it said.

Marc Branson, the FINMA chief executive, said the risk of money laundering in Switzerland — the world’s top hub for wealth management — has increased in the last couple of years as bank clients increasingly come from around the world and bring more assets from developing markets with uncertain origins.

“Therefore, the source of their wealth is harder to determine — and their transactions are perhaps harder to understand,” Branson told The Associated Press at a news conference in the Swiss capital. He said some banks had not strengthened their “control processes.”

“The warning signals were there, but were not acted on,” he said, alluding to cases of banks that violated the anti-money laundering requirements. “That’s where we step in and say: ‘That goes over the line — and that, we cannot accept.'”

FINMA has close three cases linked to banks with ties to 1MDB, involving Falcon Bank, Coutts and BSI, and is investigating four others. The only one of those four to be identified is linked to UBS, after Singaporean authorities announced their own probe of the Swiss banking heavyweight in October, authority spokesman Vinzenz Mathys said.

FINMA later issued a correction, with Mathys saying the case had been closed in the last few days, with UBS receiving a reprimand for not adequately clarifying a number of transactions — but that no “systematic” issues were found.

FINMA Chairman Thomas Bauer also said that the authority was not contacted by investigators behind a Dutch-led probe announced last week of suspected money laundering and tax evasion linked to Credit Suisse. He said judicial and tax authorities, not financial authorities, were in charge.

Jamey Keaten, The Associated Press

Cenovus prices US$2.9 billion offering of senior notes

April 4, 2017 by The Canadian Press

FOR: CENOVUS ENERGY INC.TSX Symbol: CVENYSE Symbol: CVEDate issue: April 04, 2017Time in: 5:41 PM eAttention:
Offering is part of previously announced plan to finance asset acquisition
CALGARY, AB –(Marketwired – April 04, 2017) – Cenovus Energy Inc….

Leucrotta Announces a Significant Increase in Production and a Material Extension to the Boundaries of Company’s Lower Montney Turbidite Light Oil Resource Play

April 4, 2017 by The Canadian Press

FOR: LEUCROTTA EXPLORATION INC.TSX VENTURE SYMBOL: LXEDate issue: April 04, 2017Time in: 4:35 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 4, 2017) – Leucrotta Exploration Inc.
(“Leucrotta” or the “Company”) (TSX VENTURE:LXE) is pleased to ann…

Enbridge and NDT Global Advance Research and Development of Next Generation Pipeline Inspection Technology

April 4, 2017 by The Canadian Press

FOR: ENBRIDGE INC.TSX SYMBOL: ENBNYSE SYMBOL: ENBAND NDT GLOBAL
Date issue: April 04, 2017Time in: 9:00 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 4, 2017) –
Editors Note: There is a photo associated with this press release.
Enbridge Inc. (“…

Intelex to Host Top EHSQ Executives at Inaugural Leadership Summit

April 4, 2017 by The Canadian Press

FOR: INTELEX TECHNOLOGIES, INC.
Date issue: April 04, 2017Time in: 9:00 AM eAttention:
Conference highlights new opportunities to reduce risk and protect
goodwill with EHSQ data
TORONTO, ON –(Marketwired – April 04, 2017) – Intelex Technologies, a wo…

Spartan Energy Corp. Announces First Quarter Operations Update and Provides Updated Corporate Presentation

April 4, 2017 by The Canadian Press

FOR: SPARTAN ENERGY CORP.TSX SYMBOL: SPEDate issue: April 04, 2017Time in: 8:30 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 4, 2017) – Spartan Energy Corp.
(“Spartan” or the “Company”) (TSX:SPE) is pleased to provide an update of its
first qu…

C-COM Integrates NovelSat Modem With iNetVu(R) Mobile Antennas

April 4, 2017 by The Canadian Press

Midwest Energy Emissions Corp. Secures Contract Renewal in Excess of $5.0 Million with Utility Customer in the Midwest U.S.

April 4, 2017 by The Canadian Press

Solar Alliance Signs Letter of Intent for Acquisition of U.S. Solar Assets

April 4, 2017 by The Canadian Press

FOR: SOLAR ALLIANCE ENERGY, INC.TSX VENTURE Symbol: SANOTCQB Symbol: SAENFDate issue: April 04, 2017Time in: 8:00 AM eAttention:
Accretive acquisition would immediately increase revenues and expand
geographic diversification
VANCOUVER, BC –(Marketwire…

Enercare Inc. Announces Monthly Dividend

April 4, 2017 by The Canadian Press

FOR: ENERCARE INC.TSX Symbol: ECIDate issue: April 04, 2017Time in: 7:30 AM eAttention:
TORONTO, ON –(Marketwired – April 04, 2017) – Enercare Inc. (“Enercare”)
(TSX: ECI) today announced a cash dividend of $0.08 per common share which
will be payabl…

Pennine announces C$3.0 million non-brokered financing to advance Albanian energy project

April 4, 2017 by The Canadian Press

FOR: PENNINE PETROLEUM CORPORATIONTSX VENTURE SYMBOL: PNNDate issue: April 04, 2017Time in: 7:01 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 4, 2017) –
NOT FOR DISTRIBUTION TO U.S. NEWSWIRE SERVICESOR FOR DISSEMINATION IN THE UNITED STATESPen…

Precision Drilling Corporation Analyst & Investor Day on Monday May 15, 2017

April 4, 2017 by The Canadian Press

FOR: PRECISION DRILLING CORPORATION
TSX SYMBOL: PD
NYSE SYMBOL: PDS

Date issue: April 04, 2017
Time in: 6:00 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 4, 2017) – Precision Drilling
Corporation (“Precision” or the “Company”) (TSX:PD)(NYSE:PDS) will host an
Analyst & Investor Day on Monday, May 15, 2017 at its Technical Service Center
in Houston, Texas. In addition to providing a comprehensive business update,
Precision’s senior management team will demonstrate recent technology
advancements as well as outline the Company’s plans regarding the
commercialization of process control automation and closed loop drilling
systems. Attendees will also have the opportunity to tour Precision’s facility
and a Super Series Triple drilling rig equipped with top tier rig
specifications and technology applications.

Those who have not already registered and wish to attend are asked to email
InvestorRelations@precisiondrilling.com and RSVP in advance of the event.

About Precision

Precision is a leading provider of safe and High Performance, High Value
services to the oil and gas industry. Precision provides customers with access
to an extensive fleet of contract drilling rigs, directional drilling services,
well service and snubbing rigs, camps, rental equipment, and wastewater
treatment units backed by a comprehensive mix of technical support services and
skilled, experienced personnel.

Precision is headquartered in Calgary, Alberta, Canada. Precision is listed on
the Toronto Stock Exchange under the trading symbol “PD” and on the New York
Stock Exchange under the trading symbol “PDS”.

– END RELEASE – 04/04/2017

For further information:
Precision Drilling Corporation
Carey Ford
Senior Vice President & Chief Financial Officer
403.716.4566
403.716.4755 (FAX)
www.precisiondrilling.com

COMPANY:
FOR: PRECISION DRILLING CORPORATION
TSX SYMBOL: PD
NYSE SYMBOL: PDS

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170404CC0012

Press Release from Marketwired 1-866-736-3779

New labour deal at Regina refinery ratified by members of Unifor union

April 3, 2017 by The Canadian Press

REGINA — A tenative labour deal at the Co-op refinery in Regina has been ratified by union members.

Both the refinery and Unifor Local 594 sent out tweets on Monday night saying the pact had been approved.

The union’s bargaining committee had said it wasn’t “the deal we wanted” but they would recommend its acceptance.

About 800 workers had been poised for a lockout starting on Sunday.

Negotiations for a new contract have been ongoing for months after the last contract expired in January 2016.

The Canadian Press

Glance Technologies Announces Expansion across Canada with Ten Restaurants signed in the past week, over 140 signed and 500 expressing Interest

April 3, 2017 by The Canadian Press

FOR: GLANCE TECHNOLOGIES INC.
CSE SYMBOL: GET
CSE SYMBOL: GET.CN
FRANKFURT SYMBOL: GJT
OTCQB SYMBOL: GLNNF

Date issue: April 04, 2017
Time in: 4:00 AM e

Attention:

VANCOUVER, BRITISH COLUMBIA–(Marketwired – April 4, 2017) – Glance
Technologies Inc., (CSE:GET)(CSE:GET.CN)(FRANKFURT:GJT)(OTCQB:GLNNF), is
pleased to announce it has signed 10 new restaurants over the past week in
several provinces, for a total of over 140 signed, and it now has 71 locations
live across major cities in Canada such as Vancouver, Toronto, Edmonton and
Victoria.

In the past month Glance Pay went live in numerous locations. Newly launched
restaurant Ricky’s all Day Grill in Victoria is a franchise within a 70
location chain spread across Western and Central Canada. In addition, within
the downtown area of Canada’s largest city, Glance Pay has launched some
strategic and well-known restaurants, such as The Good Son and Caren’s
Rosedale, and in Vancouver, well known spots The Naam Restaurant, Urban Sushi
and Elwood’s are now live.

Glance Pay’s movement into the quick-serve market has begun with the launch of
Willow Cafe in Vancouver. Willow Cafe can now offer a quick payment app with an
automatic rewards program, enabling it to compete with the larger coffee chains
and quick-serve locations that have invested heavily in their own custom apps,
like Starbucks and Tim Hortons. As sales expand to include more quick-serve
locations, Glance Pay anticipates that it will provide many small and medium
size locations a competitive edge by allowing them to offer the latest digital
experience to their customers.

“Our fast expansion across Canada over the past few months is enabled by the
ease of distributing and scaling our current payment technology,” says Penny
Green, Glance President & COO, “Glance Pay works well for any style of
restaurant or quick-serve, regardless of location and environment.”

Encompassed within Glance’s alliances are two well-known chains, MR MIKES
Steakhouse Casual and Famoso Neopolitan Pizzeria, which include 61 locations
combined. With prospective meetings and current negotiations, Glance has
engaged with more than 20 Canadian restaurant chains and has a sales pipeline
of of over 500 restaurants expressing interest and at various stages of
Glance’s sales proposal process. Prospective chains account for 50% of Glance’s
prospective sales pipeline. The remaining 50% is composed of popular,
award-winning and new-concept restaurants. Many of these restaurant chains have
subsidiaries in the U.S. and therefore align perfectly with Glance’s plan for
expansion into the U.S.

About Glance Technologies Inc.

Glance Technologies owns and operates Glance Pay, a streamlined payment system
that revolutionizes how smartphone users choose where to dine, settle bills,
access payment records and interact with merchants. Glance Pay intends to
become the industry standard as one of the four pillars of payments, beside
credit cards, debit cards and cash. Glance is building a valuable network of
merchants and consumers, and offers targeted in-app marketing, customer
feedback, in-merchant messaging and custom rewards programs. The Glance Pay
mobile payment system consists of proprietary technology, which includes user
apps available for free downloads in IOS (Apple) and Android formats, a
merchant manager app, an internal customer service app, a large scale
technology hosting environment with sophisticated anti-fraud technology and
lightning fast payment processing.

For more information about Glance, please go to Glance Technology’s website.

Forward-Looking Statements

Although Glance believes that the expectations reflected in the forward-looking
statements are reasonable, there can be no assurance that such expectations
will prove to be correct. Such forward-looking statements are subject to risks
and uncertainties that may cause actual results, performance or developments to
differ materially from those contained in the statements.

– END RELEASE – 04/04/2017

For further information:
Christina Rao
Vice President, Investor Relations
(604) 723-7480
christina@glancepay.com

COMPANY:
FOR: GLANCE TECHNOLOGIES INC.
CSE SYMBOL: GET
CSE SYMBOL: GET.CN
FRANKFURT SYMBOL: GJT
OTCQB SYMBOL: GLNNF

INDUSTRY: Professional Services – Advertising, PR and Marketing
RELEASE ID: 20170404CC0008

Press Release from Marketwired 1-866-736-3779

Carl Introduces Communications Solutions to Collect Sensor Data

April 3, 2017 by The Canadian Press

FOR: CARL DATA SOLUTIONS INC.
CSE SYMBOL: CRL
FRANKFURT SYMBOL: 7C5
CSE SYMBOL: CRL.CN
OTC PINK SYMBOL: CDTAF

Date issue: April 04, 2017
Time in: 4:00 AM e

Attention:

VANCOUVER, BRITISH COLUMBIA–(Marketwired – April 4, 2017) – Carl Data
Solutions Inc. (CSE:CRL)(CSE:CRL.CN)(FRANKFURT:7C5)(OTC PINK:CDTAF) (“Carl” or
the “Company”), a developer of Big-Data-as-a-Service (“BDaaS”)-based solutions
for data integration, business intelligence, and Industrial Internet-of-Things
(“IIoT”) applications, along with recently acquired company AB Embedded Systems
Ltd. (“AB Embedded”), now provides their clients communications solutions that
collect data more efficiently and economically from their sensor networks. By
adding networked communications to its list of services, Carl is positioned to
take the lead in analytics, monitoring and reporting for IIoT verticals.

The two primary solutions use wireless, automated communications to collect
data at remote or inaccessible sensors, and transmit it through a network to a
central location for monitoring. Currently, many sensor networks and other
remote assets have their data collected manually causing time delays and
unnecessary operational costs. This is due to the limitations of cellular or
wifi availability in certain locations. New wireless RF (radio frequency)
networks allow the transmission of multiple data streams even in very remote
locations, where cellular connections are often impractical or cost prohibitive.

A “wireless mesh” network is a made up of sensors organized in a mesh topology,
transmitting to and from gateways which can be connected to the Internet. A
mesh network can self-form and self-heal making it highly reliable. When one
sensor is no longer active, the rest of the sensors can still pass along data
between each other. Directly or by hopping through intermediaries, information
reaches a central location with little delay and almost no lost data.

A LoRaWAN (low-power wide-area network) provides secure and seamless
communications among smart devices and sensors without the need of complex
installations. The network is typically laid out in a star-of-stars topology
which relays data between sensor and a central network server through standard
IP connections. To maximize both battery life and overall network capacity, the
network servers manage the data rates and RF output for each sensor
individually.

Attila Bene, AB Embedded’s President, commented, “Both mesh and LoRaWAN
networks provide reliable low-power communications that are economical enough
for large IIoT deployments. They can connect sensors for industrial uses such
as pipeline monitoring, or monitoring Smart City infrastructures, such as water
management systems, with speed and accuracy.”

Greg Johnston, Carl’s CEO, says, “Access to these easy-to-deploy, cost
effective networked communications technologies is why we chose not to go
through with the acquisition of StratoCom Solutions Corp., a company that uses
airborne meter reading. Airborne data collection methods don’t have the speed
and accessibility needed to transmit the real-time data that will provide our
clients with the level of service needed to get the most out of our analytics,
reporting and monitoring applications.”

About Carl Data Solutions Inc.

Carl Data Solutions Inc. is focused on providing next generation information
collection, storage and analytics solutions for data-centric companies.
Building on its recent acquisitions, Flow Works Inc., a company that helps its
clients analyze and understand all forms of environmental data through a
powerful platform of data collection, monitoring, analysis and reporting tools
and ETS., Carl continues to develop applications to work with new cloud-based
mass storage services and analytics tools (Big-Data-as-a-Service (“BDaaS”)).

Carl’s development platform can accommodate virtually unlimited storage of any
type of data. This technology allows Carl to build advanced applications for
monitoring, reporting and analysis. Carl’s data collection and storage methods
allow the company to build smart Software-as-a-Service (“SaaS”)-based
applications that can collect data from many diverse sources and provide deep
insight for decision-making purposes. More information can be found at
www.carlsolutions.com.

About AB Embedded Pvt. Ltd.

AB Embedded Pvt. Ltd. has been executing projects in hardware and software
engineering design since 2006 in Calgary, Canada. Since their embedded systems
are designed to perform specific tasks, their engineers ensure that a
customers’ cost, power consumption, size and performance are optimized. Their
smart control systems and devices are manufactured specifically for water,
solid waste management, industrial control and monitoring in all-weather
environments.

AB Embedded’s high-performance, high-efficiency control systems work well for
the Oil & Gas sector because of their consistent reliability and low-power
consumption. AB Embedded believes in constant innovation. They are transforming
the way engineers design, prototype and deploy embedded systems for automation,
measurement and embedded applications. www.ab-embedded.com

On behalf of the Board of Directors:

Greg Johnston, President, Chief Executive Officer, Director

Carl Data Solutions Inc.

The Canadian Securities Exchange (operated by CNSX Markets Inc.) has neither
approved nor disapproved of the contents of this press release.

– END RELEASE – 04/04/2017

For further information:
Carl Data Solutions Inc.
Kimberly Bruce
Corporate Communications
(778) 379-0275
kimberly@carlsolutions.com
www.carlsolutions.com

COMPANY:
FOR: CARL DATA SOLUTIONS INC.
CSE SYMBOL: CRL
FRANKFURT SYMBOL: 7C5
CSE SYMBOL: CRL.CN
OTC PINK SYMBOL: CDTAF

INDUSTRY: Computers and Software – Internet, Computers and Software
– Software
RELEASE ID: 20170404CC0007

Press Release from Marketwired 1-866-736-3779

Versus Systems to Present at the MicroCap Conference in New York City at the Essex House

April 3, 2017 by The Canadian Press

FOR: VERSUS SYSTEMS INC.
CSE SYMBOL: VS
CSE SYMBOL: VS.CN
OTCQB SYMBOL: VRSSF
FRANKFURT SYMBOL: BMVA

Date issue: April 04, 2017
Time in: 3:01 AM e

Attention:

NEW YORK, NEW YORK–(Marketwired – April 4, 2017) – Versus Systems, Inc.
(CSE:VS)(CSE:VS.CN)(OTCQB:VRSSF)(FRANKFURT:BMVA) announced that company
Co-Founder and CEO Matthew Pierce will be presenting at this year’s MicroCap
Conference today, April 4th in New York City.

Versus Systems, Inc. has developed a proprietary in-game prizing and promotions
engine featuring conditional prizing and dynamic regulatory compliance. Versus
allows brands to engage the $1.5 billion gaming audience in a completely
organic way – through prized base competitions. Players can select gear,
apparel, concert tickets, energy drinks, DLC, and cash – all from brands gamers
care about like Rockstar, Han Cholo, Tier 1 Games and others. Versus wants
every gamer at home to feel like an eSports phenomenon, playing for real stakes
and real prizes. See how Versus works here:
https://www.youtube.com/watch?v=a37iab8qGbY&feature=youtu.be

CONFERENCE OVERVIEW AND STRUCTURE

The MicroCap Conference is an exclusive event for investors who specialize in
small and microcap stocks. It is an opportunity to be introduced to and speak
with management at some of the most attractive small companies, learn from
various expert panels, and mingle with other microcap investors.

The MicroCap Conference will take place in New York City at the Essex House on
April 4th. Registration will begin on Tuesday at 7:00AM, and will last until
the evening. These days will be jam-packed with company sessions,
presentations, good food, and plenty of time to network with other investors
over drinks at the reception. This event does not allow service providers –
only portfolio managers, analysts, and private investors.

REGISTRATION FOR INVESTORS

To register, please go to our website (www.microcapconf.com), and click
“Register”

MARQUEE SPONSORS

The Special Equities Group

Maxim Group

FOR CONFERENCE INFORMATION

Please visit: www.microcapconf.com

Or, contact Tony Yu at tony@microcapconf.com

Reader Advisory

Certain statements in this release are forward-looking statements, which
include regulatory approvals, development of technology, timing of completion
of technology and other matters. Forward-looking statements consist of
statements that are not purely historical, including any statements regarding
beliefs, plans, expectations or intentions regarding the future. Such
information can generally be identified by the use of forwarding looking
wording such as “may”, “expect”, “estimate”, “anticipate”, “intend”, “believe”
and “continue” or the negative thereof or similar variations. Readers are
cautioned not to place undue reliance on forward-looking statements, as there
can be no assurance that the plans, intentions or expectations upon which they
are based will occur. By their nature, forward-looking statements involve
numerous assumptions, known and unknown risks and uncertainties, both general
and specific, that contribute to the possibility that the predictions,
estimates, forecasts, projections and other forward looking statements will not
occur. Forward-looking statements contained in this press release are expressly
qualified by this cautionary statement. Forward-looking information is based on
certain key expectations and assumptions made by the management of the Company
including the development of its technology, including the effectiveness of the
technology. Although the Company believes that the expectations and assumptions
on which such forward-looking information is based are reasonable, undue
reliance should not be placed on the forward-looking information because the
Company can give no assurance that they will prove to be correct. There can be
no assurance that such statements will prove to be accurate and actual results
and future events could differ materially from those anticipated in such
statements. Important factors that could cause actual results to differ
materially from the Company’s expectations include consumer sentiment towards
the Company’s technology, technology failures, competition, and failure of
counterparties to perform their contractual obligations and other risks
detailed from time to time in the filings made by the Company in securities
filings.

The forward-looking statements contained in this press release are made as of
the date of this press release. Except as required by law, the Company
disclaims any intention and assumes no obligation to update or revise any
forward-looking statements, whether as a result of new information, future
events or otherwise. Additionally, the Company undertakes no obligation to
comment on the expectations of, or statements made by, third parties in respect
of the matters discussed above.

The Canadian Securities Exchange has not reviewed, nor approved the content of
the contents of this news release.

– END RELEASE – 04/04/2017

For further information:
Versus Systems, Inc.
Liz Pieri
liz@pieripr.com
626-818-7580

COMPANY:
FOR: VERSUS SYSTEMS INC.
CSE SYMBOL: VS
CSE SYMBOL: VS.CN
OTCQB SYMBOL: VRSSF
FRANKFURT SYMBOL: BMVA

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170404CC0005

Press Release from Marketwired 1-866-736-3779

City council votes to avoid banking with Keystone XL backers

April 3, 2017 by The Canadian Press

SEATTLE — The Seattle City Council has voted to oppose the Keystone XL Pipeline and to request that the city’s finance department avoid contracting with banks that back the $8 billion project.

The Seattle Times reports (https://goo.gl/imAhny ) the council voted unanimously Monday to pass the resolution. The Trump administration signed off on the pipeline last month, reversing the Obama administration’s rejection of the pipeline.

The Keystone XL wouldn’t pass through Seattle but anti-pipeline activists say the project would contribute to devastating climate change.

The council passed legislation earlier this year requesting that Mayor Ed Murray not renew a Wells Fargo contract because of the bank’s role as a lender for the Dakota Access Pipeline project. The city will wait until that contract expires at the end of next year rather than severing ties immediately.

___

Information from: The Seattle Times, http://www.seattletimes.com

The Associated Press

Pipeline owner says Alaska spill was less than 3 gallons

April 3, 2017April 3, 2017 by The Canadian Press

ANCHORAGE, Alaska — An underwater pipeline that sprung a leak in Alaska’s Cook Inlet, an area known for diverse marine life, probably dumped less than three gallons (11 litres) of crude oil into the ocean, the pipeline’s owner said Monday.

The spill between two production platforms owned by Hilcorp Alaska LLC was spotted Saturday. Cook Inlet stretches 180 miles (290 kilometres) from the Gulf of Alaska to Anchorage and is home to an endangered population of beluga whales.

Hilcorp by Sunday had removed all oil from the 8-inch (20.3-centimetre) diameter pipeline.

Cook Inlet is also habitat for humpback whales, the western population of Steller sea lions and northern sea otters. Harbor seals, killer whales and porpoise use the inlet.

The Kenai Peninsula makes up the eastern side of the inlet and draws thousands of anglers every summer seeking halibut in the inlet or salmon in ocean water and streams.

The spill volume was estimated from the size of sheens that were seen, said company spokeswoman Lori Nelson in an emailed response to questions. The sheens dissipated, Nelson said.

In three flyovers Sunday and a final one Monday morning, no additional sheens were spotted from the air.

Hilcorp, the Coast Guard and state environmental authorities over the weekend formed a unified command in response to the spill that was suspended Monday, said Candice Bressler, spokeswoman for the Alaska Department of Environmental Conservation.

The leak’s cause was unknown.

The leak is the second in Cook Inlet this year for Hilcorp Alaska, a subsidiary of Houston-based Hilcorp.

In an unrelated incident, processed natural gas continues to spew into the inlet from an underwater pipeline that supplies four other production platforms.

The platforms burn natural gas for power. That leak was discovered in February and company officials estimate it has been leaking since mid-December.

Hilcorp says the gas leak will be repaired after floating ice no longer poses a threat to divers who would perform repairs.

The oil leak was discovered Saturday when workers on the Anna Platform “felt an impact,” according to the DEC. They spotted an oil sheen and bubbling in the water near one of the platform’s legs.

The suspected leaking line connects Anna Platform with Bruce Platform in 75 feet (23 metres) of water.

The 1.6-mile (2.6-kilometre) line has a capacity of 19,362 gallons (73,291 litres) and was full. Hilcorp Alaska shut down the platform and lowered pressure in the pipeline to zero.

Overflights spotted six sheens. The largest was 10-by-12 feet (3-by-3.7 metres).

Bressler said Hilcorp used a polyurethane “pig,” a device inserted into the pipe, to push remaining crude oil toward the Bruce Platform. It was processed and moved to a tank farm.

Hilcorp has detected no harm to wildlife, Nelson said.

Dan Joling, The Associated Press

Savanna Announces Considerations for Minority Shareholders

April 3, 2017 by The Canadian Press

FOR: SAVANNA ENERGY SERVICES CORP.TSX SYMBOL: SVYDate issue: April 03, 2017Time in: 8:16 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 3, 2017) – Savanna Energy Services Corp.
(“Savanna”) (TSX:SVY) wishes to address certain matters with respect…

PetroShale Announces Filing of Final Prospectus and Entering Into of Agency Agreement

April 3, 2017 by The Canadian Press

FOR: PETROSHALE INC.TSX VENTURE SYMBOL: PSHOTCQX SYMBOL: PSHIFDate issue: April 03, 2017Time in: 7:23 PM eAttention:
CALGARY, ALBERTA–(Marketwired – April 3, 2017) –
NOT FOR DISTRIBUTION TO U.S. NEWSWIRE SERVICES OR FOR DISSEMINATION IN THE
UNITED STA…

Xtreme Drilling Corp. Announces Additional Strategic Initiatives to Deliver Value to Shareholders and Increase Competitiveness in US Resource Plays

April 3, 2017 by The Canadian Press

FOR: XTREME DRILLING CORP.
TSX SYMBOL: XDC

Date issue: April 03, 2017
Time in: 5:52 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 3, 2017) – Xtreme Drilling Corp.
(“Xtreme”, the “Company”) (TSX:XDC) is pleased to announce the next steps in
the strategic direction of the Company.

The recent announcement of the 850XE rig upgrades and the XDR 500 optimization
program was the first step in the Company’s strategy to re-position Xtreme as a
high-spec United States shale focused drilling contractor. The Company believes
that by leveraging its heritage of technology and innovation, it can provide
best in class rigs to customers in the recovering United States shale drilling
market.

The Company is initiating two additional steps to further focus the
organization and enhance shareholder value. These additional steps include the
commencement of a substantial issuer bid to purchase Xtreme common shares
(“Xtreme Shares”) and an intention to explore strategic options with respect to
the eight shallower capacity AC electric XDR 200 and 300 drilling rigs.

The recent increase in US active drilling rigs has been dominated by high
specification AC electric rigs. It is estimated by industry sources that since
activity levels bottomed in the second quarter of 2016 that more than 80% of
the increase in the rig count was in the high or super-spec segment of the
market. The Company believes that the demand for deep capacity high-spec AC
electric rigs will continue in the future. By the end of 2017 Xtreme will have
13 rigs that fit this category, ten XDR 500 and three 850XE rigs.

“This two-pronged plan enables us to immediately return meaningful value to
Xtreme shareholders and further focus our efforts in the major US resource
plays,” said Matt Porter, President and Chief Executive Officer. “We believe
this plan makes best use of our strong balance sheet and cash position as it
allows the Company to maintain considerable flexibility for opportunities in
our core high-spec US drilling business while continuing to provide liquidity
and return of capital to our shareholders.”

Substantial Issuer Bid

The Company intends to undertake a substantial issuer bid to purchase up to an
aggregate of $25 million in Xtreme Shares through a Dutch Auction tender
process (the “Proposed Issuer Bid”). The Proposed Issuer Bid demonstrates
Xtreme’s confidence in the strength of the business and commitment to
delivering shareholder value through the return of capital and enhancing
liquidity to shareholders that elect to tender their Xtreme Shares. The Company
believes that the growth prospects, long-term strategy and associated cash flow
are not accurately reflected by the Company’s current price of Xtreme Shares.

The Board of Directors has appointed an independent committee of the Directors
to set the price and details around the Proposed Issuer Bid.

XDR 200/300 Strategic Review

In addition, the Company is evaluating strategic options with respect to its
four XDR 200 and four XDR 300 AC electric drilling rigs. These rigs were
designed and built by Xtreme and have leading edge AC electric technology. Due
to the shallower depth capacities (up to 3,500 meters) of these rigs they are
ideally suited for the Canadian or international drilling markets and do not
align with Xtreme’s focus on the deeper basins of the United States. The
Company will continue to operate the existing three rig XDR 200 operation in
Canada while strategic options are evaluated. The Company is reviewing
international opportunities to deploy the rigs alongside the potential for an
outright sale.

As the Company moves forward in a lower priced commodity environment, the
strategy set forth improves Xtreme’s competitiveness and should ultimately
enhance value to shareholders.

Operations Update

Currently, the Company has seven of ten XDR 500 rigs contracted and is in the
process of finalizing a contract for an eighth XDR 500, which the Company
anticipates to commence work later in Q2 2017.

The Company is currently in the initial stages of upgrading the three
super-spec 850XE rigs with anticipated delivery of one rig in Q3 2017 and the
remaining two rigs in Q4 of 2017. The first rig was recently contracted on a 24
month term contract to an operator in Oklahoma. The commercial conversations
for the final two 850XE rigs remain very encouraging and Xtreme anticipates an
additional rig to be contracted in the second quarter for a Q4 2017 delivery.

Reader Advisory

This news release, or documents incorporated herein, contains forward-looking
information (“FLI”). FLI is typically contained in statements with words such
as “anticipate”, “believe”, “estimate”, “expect”, “plan”, “schedule”, “should”,
“intend”, “propose” or similar words suggesting future outcomes or an outlook.
More particularly, this news release contains FLI that may relate to: demand,
rig availability, growth prospects, associated cash flows, rig markets,
contracting and timing related thereto, deployment, operation, marketing,
financing, our intention to undertake the Proposed Issuer Bid and the terms
thereof including the maximum size of the Proposed Issuer Bid, long-term
strategy, strategic options, strategic expectations including the impact on
Xtreme of the Proposed Issuer Bid and/or the sale of the XDR 200 and 300 AC
electric drilling rigs (“XDR 200/300 Rigs”), construction, modifications and
utilization of drilling rigs in the Company’s current and future fleet.
Although Xtreme believes expectations reflected in such FLI are reasonable,
readers should not place undue reliance on them because Xtreme can give no
assurance they will prove to be correct. There are many factors that could
cause FLI not to be correct, including risks and uncertainties inherent in the
Company’s business.

FLI is based on certain factors and assumptions including, but not limited to:
the assessment of current and projected future drilling and related operations,
the assessment of the competitive marketplace, ongoing and future strategic
business alliances, negotiations and opportunities to enter new, extend or
complete existing contracts, the availability and cost of financing, currency
exchange rates, timing and magnitude of capital expenditures, expenses and
other variables affecting rig operation, modification and construction, the
ability and commitment of vendors to provide rig equipment, services and
supplies, including labor, in a cost-effective and timely manner, the issuance
of applied-for patents, changes in tax structures and rates and government
regulations.

Although Xtreme considers the assumptions used to prepare this news release
reasonable, based on information available to management as of April 3, 2017,
ultimately the assumptions may prove to be incorrect. FLI is also subject to
certain factors, including risks and uncertainties, which could cause actual
results to differ materially from management’s current expectations. These
factors include, but are not limited to: the cyclical nature of drilling market
demand, currency exchange rates and commodity prices, access to credit and to
equity markets, the availability and retention of qualified personnel,
vendor-provided equipment components and services, competition for customers,
the market for the XDR 200/300 Rigs and the ability of Xtreme to secure an
attractive price for these rigs, the Proposed Issuer Bid not occurring at all
or not occurring as expected including any failure of any condition to the
Proposed Issuer Bid, any inability to obtain any necessary regulatory approvals
or exemptive relief in connection with the Proposed Issuer Bid, the extent to
which holders of Xtreme Shares elect to tender their Xtreme Shares under the
Proposed Issuer Bid, Xtreme having sufficient financial resources and working
capital following completion of the Proposed Issuer Bid (including to fund
Xtreme’s currently anticipated financial obligations and to pursue desirable
business opportunities), the market for the Xtreme Shares at the completion of
the Proposed Issuer Bid being materially less liquid than the market that
exists at the time we commence it, timing around the Proposed Issuer Bid being
launched and completed and the effect the Proposed Issuer Bid and/or the sale
of the XDR 200/300 Rigs have on Xtreme as a whole. Other than with respect to
the Proposed Issuer Bid and the XDR 200/300 Rigs sale, the foregoing and other
material risks and uncertainties are discussed in our public filings at
www.sedar.com, including in our MD&A and Annual Information Form.

Management’s assumptions considered the following: ongoing access to key
services, supplies and equipment required to continue operating and maintaining
the rigs, including fuel, continued successful performance of drilling and
related equipment, expectations regarding gross margin, recruitment and
retention of qualified personnel, continuation or extension of existing
long-term, multi-well contracts or other contracts, revenue expectations
related to shorter-term drilling opportunities, willingness and ability of
customers to remit amounts owing to Xtreme in accordance with normal industry
practices, and management of accounts receivable in direct relation to revenue
generation.

In preparing this news release, the following risk factors were considered:
fluctuations in crude oil and natural gas prices, as well as supply and demand,
fluctuation in currency exchange and interest rates, financial stability of
Xtreme’s customers, current and future applications for Xtreme’s proprietary
technology, related services provided by, and competition from, other drilling
contractors, regulatory and economic conditions in regions where Xtreme
operates, environmental constraints, changes to government legislation,
international trade barriers or restrictions, and, where appropriate, global
economic, political and military events, as well as acts of terrorism, riots,
strikes, insurrections, revolutions and civil war.

FLI contained in this news release about any prospective results of operations,
financial position or cash provided by operating activities is based on
assumptions about future events, including economic conditions and proposed
courses of action, and on management’s assessment of relevant information
currently available. Readers are cautioned such financial outlook information
contained in this news release is not appropriate for purposes other than for
which it is disclosed here. Readers should not place undue importance on FLI
and should not rely on this information as of any other date. Except as
required pursuant to applicable securities laws, Xtreme disclaims any
intention, and assumes no obligation, to update publicly or revise FLI to
reflect actual results, whether as a result of new information, future events,
changes in assumptions, changes in factors affecting such FLI or otherwise.

The Proposed Issuer Bid referred to in this news release has not yet commenced.
This news release is neither an offer to purchase nor a solicitation of an
offer to sell any common shares of Xtreme. Any solicitation and the offer to
purchase Xtreme common shares by Xtreme will be made pursuant to an offer to
purchase, issuer bid circular, letter of transmittal and related materials that
Xtreme will file with applicable securities authorities and Xtreme will
distribute these materials to its shareholders. Copies of these materials will
be available free of charge at www.sedar.com. These materials will contain
important information about the Proposed Issuer Bid and Xtreme shareholders are
urged to read them carefully, if and, when they become available.

About Xtreme

Xtreme Drilling Corp. (“XDC” on the Toronto Stock Exchange) designs, builds,
and operates a fleet of high specification AC drilling rigs featuring
leading-edge proprietary technology. Currently Xtreme operates one service line
– Drilling Services (XDR) under contracts with oil and natural gas exploration
and production companies and integrated oilfield service providers in Canada
and the United States. For more information about the Company, please visit
www.xdccorp.com.

– END RELEASE – 03/04/2017

For further information:
Xtreme Drilling Corp.
Matt Porter
President and Chief Executive Officer
+1 281 994 4600
ir@xdccorp.com
www.xdccorp.com

COMPANY:
FOR: XTREME DRILLING CORP.
TSX SYMBOL: XDC

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170403CC0111

Press Release from Marketwired 1-866-736-3779

Bonavista Energy Corporation Announces Increase to Exchangeable Share Ratio

April 3, 2017 by The Canadian Press

FOR: BONAVISTA ENERGY CORPORATION
TSX SYMBOL: BNP

Date issue: April 03, 2017
Time in: 5:49 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 3, 2017) – Bonavista Energy Corporation
(TSX:BNP) (“Bonavista”) is pleased to announce the increase to the Exchange
Ratio of its exchangeable shares from 1.43223 to 1.43643. This increase will be
effective on April 17, 2017 (the “Effective Date”).

The following are the details of the calculation of the Exchange Ratio:

/T/

—————————————————————————-

Five day
Weighted
Average
Trading
Price of
Bonavista
common Effective Exchange
Record Bonavista shares Date of the Ratio as of
Date of Opening Dividend (Prior to Increase in increase in the
Bonavista Exchange per common the end of Exchange Exchange Effective
Dividend Ratio share the Month) Ratio (1) Ratio Date
—————————————————————————-
March 31, April 17,
2017 1.43223 $0.01 $3.41 0.00420 2017 1.43643
—————————————————————————-
(1) The increase in the Exchange Ratio is calculated by multiplying the
Bonavista dividend per common share by the Exchange Ratio immediately
prior to the Record Date and dividing by the five day weighted average
trading price of Bonavista’s common shares.

/T/

A holder of Bonavista exchangeable shares can exchange all or a portion of
their holdings into Bonavista common shares, at any time, by giving notice to
their investment advisor or Computershare at its principal transfer office in
Suite 600, 530 – 8th Avenue S.W., Calgary, Alberta, T2P 3S8.

Please visit our website at www.bonavistaenergy.com for detailed corporate
information.

Bonavista is focused on creating premium shareholder value through the
efficient development of high quality oil and natural gas assets.

– END RELEASE – 03/04/2017

For further information:
Dean M. Kobelka
Vice President, Finance & CFO
OR
Berk Sumen
Investor Relations Lead
OR
Bonavista Energy Corporation
1500, 525 – 8th Avenue SW
Calgary, AB T2P 1G1
Phone: (403) 213-4300
Website: www.bonavistaenergy.com

COMPANY:
FOR: BONAVISTA ENERGY CORPORATION
TSX SYMBOL: BNP

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170403CC0110

Press Release from Marketwired 1-866-736-3779

Weekly Canadian Oil & Gas Industry Highlights – April 3, 2017

June 28, 2017April 3, 2017 by EnergyNow Media

April 3, 2017 Presented by POIM Consulting Group Major /Interesting Projects Rampart Oil Inc. Injection/disposal facility 13-24-014-26W4 Shell Canada Limited Gas battery – multiwall 01-28-063-20W5 Velvet Energy Ltd Gas battery – multiwall 11-02-068-03W6 Baccalieu Energy – 7 well Pad site – 03-07-038-07W5 MEG Energy Corp. Large Pad Site 09-04-077-05W4 Murphy Oil Company Ltd. 12-29-64-18W5 Pad … Read more

Serinus Energy Announces Executive Appointment

April 3, 2017 by The Canadian Press

FOR: SERINUS ENERGY INC.
TSX SYMBOL: SEN
WARSAW SYMBOL: SEN

Date issue: April 03, 2017
Time in: 4:30 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 3, 2017) – Serinus Energy Inc.
(“Serinus”, “SEN” or the “Company”) (TSX:SEN)(WARSAW:SEN) is pleased to
announce the appointment of Mr. Trevor Rath as Vice President, Operations. Mr.
Rath has a wealth of oil and gas operations and engineering experience,
including drilling, completions, production and facilities. For the past two
years Mr. Rath has worked as a consultant to various oil and gas companies.
Prior to that, he was Country Operations Manager for Storm International
Ventures in Tunisia. The Company looks forward to Trevor’s contributions to the
Company’s operations.

Serinus is an international upstream oil and gas exploration and production
company that owns and operates projects in Tunisia and Romania.

For further information, please refer to the Serinus website
(www.serinusenergy.com).

Translation: This news release has been translated into Polish from the English
original.

Forward-looking Statements This release may contain forward-looking statements
made as of the date of this announcement with respect to future activities that
either are not or may not be historical facts. Although the Company believes
that its expectations reflected in the forward-looking statements are
reasonable as of the date hereof, any potential results suggested by such
statements involve risk and uncertainties and no assurance can be given that
actual results will be consistent with these forward-looking statements.
Various factors that could impair or prevent the Company from completing the
expected activities on its projects include that the Company’s projects
experience technical and mechanical problems, there are changes in product
prices, failure to obtain regulatory approvals, the state of the national or
international monetary, oil and gas, financial, political and economic markets
in the jurisdictions where the Company operates and other risks not anticipated
by the Company or disclosed in the Company’s published material. Since
forward-looking statements address future events and conditions, by their very
nature, they involve inherent risks and uncertainties and actual results may
vary materially from those expressed in the forward-looking statement. The
Company undertakes no obligation to revise or update any forward-looking
statements in this announcement to reflect events or circumstances after the
date of this announcement, unless required by law.

– END RELEASE – 03/04/2017

For further information:
Serinus Energy Inc. – Canada
Calvin Brackman
Vice President, External Relations & Strategy
+1-403-264-8877
cbrackman@serinusenergy.com
OR
Serinus Energy Inc.
Jeffrey Auld
Chief Executive Officer
+1-403-264-8877
jauld@serinusenergy.com

COMPANY:
FOR: SERINUS ENERGY INC.
TSX SYMBOL: SEN
WARSAW SYMBOL: SEN

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170403CC0098

Press Release from Marketwired 1-866-736-3779

Leucrotta Exploration Announces 2016 Year-End Reserves

April 3, 2017 by The Canadian Press

FOR: LEUCROTTA EXPLORATION INC.
TSX VENTURE SYMBOL: LXE

Date issue: April 03, 2017
Time in: 4:25 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 3, 2017) – Leucrotta Exploration Inc.
(“Leucrotta” or the “Company”) (TSX VENTURE:LXE) is pleased to announce its
2016 year-end reserves as independently evaluated by GLJ Petroleum Consultants
Ltd. (“GLJ”) effective December 31, 2016 (the “GLJ Report”), in accordance with
National Instrument 51-101 (“NI 51-101”) and Canadian Oil and Gas Evaluation
(COGE) Handbook. All dollar figures are Canadian dollars unless otherwise noted.

2016 Highlights

/T/

— Increased proved plus probable reserves by 32% to 22.7 million barrels

of oil equivalent (“boe”)
— Increased proved reserves by 25% to 10.2 million boe
— Reserve replacement of 1,566% on a proved plus probable basis and 644%
on a proved basis
— Achieved finding and development costs including changes in future
development capital (“FDC”) but excluding land and property
acquisitions/dispositions on a proved plus probable basis of $7.00 per
boe
— Cumulative booked reserves on only 5 net sections of 141 net sections in
the Doe/Mica Montney Core area
— Subsequent to year-end, converted approximately 2.8 million boes from
the non-producing category to the producing category

/T/

Overview

Leucrotta continued its plan of spending capital on wide area delineation of
the Lower Montney Turbidite in the Doe/Mica area where it has accumulated 141
net sections of Montney land. Leucrotta has maintained a conservative
philosophy to booking reserves and has only booked locations immediately
offsetting previously drilled wells but covering a large geographic area. A
total of 2 new wells and 6 new locations were booked in the Doe East and Mica
areas in 2016 while leaving the Doe bookings static from 2015 to 2016. For
additional information on reserves assigned to these drilling locations please
see “Forward Looking Information – Potential Drilling Locations” at the end of
this news release. Leucrotta also has the current financial capability
(assuming pricing and performance are comparable to the GLJ Report) to execute
on the $96 million of FDC included in the GLJ Report and therefore realize on
the values presented.

Leucrotta has estimated, based on mapping and other technical data, that it has
up to 780 potential Montney drilling locations (predominantly in the Lower
Montney Turbidite) of which 20 have been booked in the reserve report. For
additional information on reserves assigned to these drilling locations please
see “Forward Looking Information – Potential Drilling Locations” at the end of
this news release. Should Leucrotta be able to obtain similar drilling results
on future wells, there is a large potential value to be booked and subsequently
realized on given Leucrotta’s large unbooked drilling inventory.

Leucrotta’s capital expenditures were focused predominantly in the Doe/Mica
area to expand its land base, improve and expand infrastructure, and start to
delineate its large Montney land base. Capital allocation by category is as
follows:

Capital Expenditures

/T/

($000s) 2016 2015
—————————————————————————-
Undeveloped land 4,882 15,381
Facility equipment not in use and held for sale 2,784 18,040
Equipment disposition (4,000) –
Property disposition – (79,342)
—————————————————————————-
Sub-total acquisitions/dispositions 3,666 (45,921)

Drilling and completion 7,657 19,460
Facilities and related infrastructure 6,859 5,643
Geological, geophysical and other 392 713
—————————————————————————-
Sub-total capital expenditures 14,908 25,816

—————————————————————————-
Total all-in capital 18,574 (20,105)
—————————————————————————-
—————————————————————————-

/T/

During 2016 the Company added Montney acreage adjacent to its Montney land base
through both Crown land sales and private land acquisitions as well as began
the pipeline system and infrastructure required to tie-in previously drilled
wells to the Company’s Doe gas plant. This pipeline and infrastructure spending
continued into Q1 2017 and four previously drilled wells were subsequently
tied-in and began producing. In the fourth quarter of 2016 the Company drilled
three wells (3.0 net) resulting in two successful light oil wells in Mica (one
completed in Q4 2016 and the other in Q1 2017) and one vertical test well.

Reserve Additions

Leucrotta continued to have positive results in its Montney delineation and
development in the Dawson area of British Columbia.

A total of eight additional wells were booked this year in the Mica and East
Doe areas and accounted for the majority of the reserve adds this year. Based
on the GLJ Report, the additional wells accounted for an increase of 2.4 mmboes
in the proved category and 6.0 mmboes in the proved plus probable category

Leucrotta has only booked reserves to a portion of 8 sections (5 net) of its
total 141 net sections of Montney land in the greater Dawson area. The bookings
leave a material amount of land for potential future bookings and provides for
a manageable amount of FDC booked ($95.7 million on a proved plus probable
basis) relative to Leucrotta’s current financial capabilities.

Reserves Summary

Leucrotta’s December 31, 2016 reserves as prepared by GLJ effective December
31, 2016 and based on the GLJ (2017-01) future price forecast are as follows
(1,4):

/T/

—————————————————————————-

Conventional Shale
Working Light/ Natural Natural Total Oil
Interest Medium Oil Tight Oil Gas Gas NGLs Equivalent
Reserves (2) (Mbbl) (Mbbl) (Mbbl) (Mmcf) (Mbbl) (Mboe) (3)
—————————————————————————-
Proved
—————————————————————————-
Producing 55 79 52 5,756 197 1,299
—————————————————————————-
Developed
non-
producing 0 201 144 11,578 378 2,533
—————————————————————————-
Undeveloped 0 109 0 31,894 981 6,405
—————————————————————————-
Total proved 55 388 196 49,227 1,556 10,237
—————————————————————————-
Probable 22 391 53 60,520 1,948 12,456
—————————————————————————-
Total proved &
probable 77 780 250 109,747 3,504 22,693
—————————————————————————-
Notes:
(1) Numbers may not add due to rounding.
(2) “Working Interest” reserves means Leucrotta’s working interest
(operating and non-operating) share before deduction of royalties and
without including any royalty interest of Leucrotta.
(3) Oil equivalent amounts have been calculated using a conversion rate
of six thousand cubic feet of natural gas to one barrel of oil.
(4) See the Company’s Annual Information Form (“AIF”) available on SEDAR
at www.sedar.com for the disclosure of Net reserves. “Net” reserves
means Leucrotta’s working interest (operated and non-operated) share
after deduction of royalties, plus Leucrotta’s royalty interest in
reserves.

/T/

Reserves Values

The estimated future net revenues before taxes associated with Leucrotta’s
reserves effective December 31, 2016 and based on the GLJ (2017-01) future
price forecast are summarized in the following table (1,2,3,4):

/T/

—————————————————————————-

Discount factor per year
—————————————————————————-
($000s) 0% 5% 10% 15% 20%
—————————————————————————-
Proved
—————————————————————————-
Producing 13,359 11,474 10,097 9,062 8,262
—————————————————————————-
Developed Non-producing 38,813 29,060 22,724 18,423 15,371
—————————————————————————-
Undeveloped 78,618 50,658 34,851 25,177 18,833
—————————————————————————-
Total proved 130,790 91,193 67,671 52,662 42,466
—————————————————————————-
Probable 231,069 130,389 84,053 59,322 44,511
—————————————————————————-
Total proved & probable 361,859 221,582 151,725 111,985 86,977
—————————————————————————-
Notes:
(1) Numbers may not add due to rounding.
(2) The estimated future net revenues are stated prior to provision for
interest, debt service charges or general administrative expenses and
after deduction of royalties, operating costs, estimated well
abandonment and reclamation costs and estimated future capital
expenditures.
(3) The estimated future net revenue contained in the table does not
necessarily represent the fair market value of the reserves. There is
no assurance that the forecast price and cost assumptions contained
in the GLJ Report will be attained and variations could be material.
The recovery and reserve estimates described herein are estimates
only. Actual reserves may be greater or less than those calculated.
(4) See the Company’s AIF available on SEDAR at www.sedar.com for the
after-tax present values of future net revenue attributed to
Leucrotta’s reserves.

/T/

Price Forecast

The GLJ (2017-01) price forecast is as follows:

/T/

—————————————————————————-

WTI Oil @ Edmonton Light AECO Natural Foreign
Cushing Oil Gas Exchange
Year ($US / Bbl) ($Cdn / Bbl) ($Cdn / Mmbtu) (US$/Cdn$)
—————————————————————————-
2017 55.00 69.33 3.46 0.750
—————————————————————————-
2018 59.00 72.26 3.10 0.775
—————————————————————————-
2019 64.00 75.00 3.27 0.800
—————————————————————————-
2020 67.00 76.36 3.49 0.825
—————————————————————————-
2021 71.00 78.82 3.67 0.850
—————————————————————————-
2022 74.00 82.35 3.86 0.850
—————————————————————————-
2023 77.00 85.88 4.05 0.850
—————————————————————————-
2024 80.00 89.41 4.16 0.850
—————————————————————————-
2025 83.00 92.94 4.24 0.850
—————————————————————————-
2026 86.05 95.61 4.32 0.850
—————————————————————————-
Escalate
thereafter (1) 2.0% per year 2.0% per year 2.0% per year
—————————————————————————-
Note:
(1) Escalated at two per cent per year starting in 2026 in the January 1,
2017 GLJ price forecast with the exception of foreign exchange, which
remains flat.

/T/

Reserve Life Index (“RLI”)

Leucrotta’s RLI presented below is based on Q4 2016 average production of 824
boepd.

/T/

—————————————————————————-
Reserve Category RLI
—————————————————————————-
Proved plus Probable Reserves 75.5
—————————————————————————-
Proved 34.0
—————————————————————————-

/T/

Finding and Development Costs (“F&D”) and Finding, Development and Acquisition
Costs (“FD&A”)

F&D costs exclude net property acquisitions/dispositions, undeveloped land
acquisitions, and gas plant equipment which was not in use. F&D costs,
including FDC, were $11.55 per boe on a proved basis and $7.00 on a proved plus
probable basis.

FD&A costs, including FDC, were $13.05 per boe on a proved basis and $7.62 on a
proved plus probable basis. The three-year comparative which normalizes the
period costs was $31.59 on a proved basis and $11.27 on a proved plus probable
basis.

FD&A costs were significantly affected by the large amount expended for land
and gas plant equipment which was not in use during 2014 to 2016 with no direct
reserve additions during these periods for these expenditures. Certain
infrastructure costs were also incurred during the period that affects all
future projects as well as current projects. Long-term FD&A will normalize both
these cost areas but 2014 to 2016 were negatively affected.

Leucrotta has presented FD&A and F&D costs below.

/T/

—————————————————————————-

2016 2015 3 Year Average

($000’s, except Proved & Proved & Proved &
where noted) Proved Probable Proved Probable Proved Probable
—————————————————————————-

F&D costs (excluding
net acquisitions/
dispositions)
Exploration and
development
expenditures 14,908 14,908 25,816 25,816 71,740 71,740
Change in FDC (1) 13,269 26,642 (7,251) (13,642) 34,670 64,659
—————————————————————————-
F&D costs excluding
net acquisitions/
dispositions
(Including FDC) 28,177 41,550 18,565 12,174 106,410 136,399

FD&A costs
(including net
acquisitions/
dispositions)

Exploration and
development
expenditures 14,908 14,908 25,816 25,816 71,740 71,740
Net acquisitions
(dispositions) 3,666 3,666 (45,921) (45,921) 29,596 29,596
—————————————————————————-
FD&A costs
including net
acquisitions/
dispositions 18,574 18,574 (20,105) (20,105) 101,336 101,336
Change in FDC 13,269 26,642 (43,795) (60,077) (1,874) 18,224
—————————————————————————-
FD&A costs including
net acquisitions/
dispositions
(Including FDC) 31,843 45,216 (63,900) (80,182) 99,462 119,560

Reserve Additions
(Mboe) (2)

Exploration and
development 2,440 5,933 1,299 1,880 9,230 19,596
Net acquisitions/
dispositions – – (6,708) (9,796) (6,081) (8,992)
—————————————————————————-
Total Reserve
Additions 2,440 5,933 (5,409) (7,916) 3,149 10,604

F&D costs excluding
net acquisitions/
dispositions
($/boe)

Excluding FDC 6.11 2.51 19.87 13.73 7.77 3.66
Including FDC 11.55 7.00 14.29 6.48 11.53 6.96

FD&A costs ($/boe)

Excluding FDC 7.61 3.13 3.72 2.54 32.18 9.56
Including FDC 13.05 7.62 11.81 10.13 31.59 11.27
—————————————————————————-
—————————————————————————-

Notes:

(1) Future development capital (“FDC”) expenditures required to recover
reserves estimated by GLJ. The aggregate of the exploration and
development costs incurred in the most recent financial period and
the change during that period in estimated future development costs
generally may not reflect total finding and development costs related
to reserve additions for that period.
(2) Sum of drilling extensions, technical revisions and economic factors
in the reserves reconciliation included in the Company’s AIF
available on SEDAR at www.sedar.com.
(3) Leucrotta was incorporated on June 10, 2014. Leucrotta commenced
active oil and natural gas operations on August 6, 2014 as a result
of the closing of a plan of arrangement involving Leucrotta, Crocotta
Energy Inc. (“Crocotta”), Long Run Exploration Ltd. and shareholders
of Crocotta, whereby Crocotta transferred its oil and natural gas
assets located in British Columbia (“BC Assets”) to Leucrotta. The
exploration and development expenditures, acquisitions expenditures,
and reserve additions presented above include those of Leucrotta from
July 10, 2014 as well as prior periods up to August 6, 2014 from the
transferred BC Assets on a carve-out basis as if they had operated as
a stand-alone entity subject to Crocotta’s control.

/T/

For Leucrotta’s full NI 51-101 disclosure related to its 2016 year-end reserves
please refer to the Company’s AIF available on SEDAR at www.sedar.com.

Forward-Looking Information

More particularly and without limitation, this document contains
forward-looking statements and information relating to the Company’s oil, NGLs
and natural gas production and reserves and reserves values, capital programs,
and oil, NGLs, and natural gas commodity prices. The forward-looking statements
and information are based on certain key expectations and assumptions made by
the Company, including expectations and assumptions relating to prevailing
commodity prices and exchange rates, applicable royalty rates and tax laws,
future well production rates, the performance of existing wells, the success of
drilling new wells, the availability of capital to undertake planned activities
and the availability and cost of labour and services.

Although the Company believes that the expectations reflected in such
forward-looking statements and information are reasonable, it can give no
assurance that such expectations will prove to be correct. Since
forward-looking statements and information address future events and
conditions, by their very nature they involve inherent risks and uncertainties.
Actual results may differ materially from those currently anticipated due to a
number of factors and risks. These include, but are not limited to, the risks
associated with the oil and gas industry in general such as operational risks
in development, exploration and production, delays or changes in plans with
respect to exploration or development projects or capital expenditures, the
uncertainty of estimates and projections relating to production rates, costs
and expenses, commodity price and exchange rate fluctuations, marketing and
transportation, environmental risks, competition, the ability to access
sufficient capital from internal and external sources and changes in tax,
royalty and environmental legislation. The forward-looking statements and
information contained in this document are made as of the date hereof for the
purpose of providing the readers with the Company’s expectations for the coming
year. The forward-looking statements and information may not be appropriate for
other purposes. The Company undertakes no obligation to update publicly or
revise any forward-looking statements or information, whether as a result of
new information, future events or otherwise, unless so required by applicable
securities laws.

Reserves Data

There are numerous uncertainties inherent in estimating quantities of light and
medium oil, tight oil, shale gas, conventional natural gas and NGLs reserves
and the future cash flows attributed to such reserves. The reserve and
associated cash flow information set forth above are estimates only. In
general, estimates of economically recoverable light and medium oil, tight oil,
shale gas, conventional natural gas and NGLs reserves and the future net cash
flows therefrom are based upon a number of variable factors and assumptions,
such as historical production from the properties, production rates, ultimate
reserve recovery, timing and amount of capital expenditures, marketability of
oil and natural gas, royalty rates, the assumed effects of regulation by
governmental agencies and future operating costs, all of which may vary
materially.

Individual properties may not reflect the same confidence level as estimates of
reserves for all properties due to the effects of aggregation.

This news release contains estimates of the net present value of the Company’s
future net revenue from its reserves. Such amounts do not represent the fair
market value of the Company’s reserves.

The reserves data contained in this news release has been prepared in
accordance with National Instrument 51-101 (“NI 51-101”). The reserve data
provided in this news release presents only a portion of the disclosure
required under NI 51-101. All of the required information will be contained in
the Company’s Annual Information Form for the year ended December 31, 2016,
available on SEDAR at www.sedar.com.

Reserves are estimated remaining quantities of oil and natural gas and related
substance anticipated to be recoverable from known accumulations, as of a given
date, based on the analysis of drilling, geological, geophysical and
engineering data; the use of established technology, and specified economic
conditions, which are generally accepted as being reasonable. Reserves are
classified according to the degree of certainty associated with the estimates
as follows:

Proved Reserves are those reserves that can be estimated with a high degree of
certainty to be recoverable. It is likely that the actual remaining quantities
recovered will exceed the estimated proved reserves.

Probable Reserves are those additional reserves that are less certain to be
recovered than proved reserves. It is equally likely that the actual remaining
quantities recovered will be greater or less than the sum of the estimated
proved plus probable reserves.

Potential Drilling Locations

This press release discloses drilling locations in four categories: (i) proved
undeveloped locations; (ii) probable undeveloped locations; (iii) unbooked
locations; and (iv) an aggregate total of (i), (ii) and (iii).

Of the 780 total potential/possible Montney locations referenced in page 1 of
this press release, only the following have been assigned reserves at December
31, 2016 as independently evaluated by GLJ, in accordance with NI 51-101:

/T/

— 9 Proved Undeveloped
— 11 Probable Undeveloped

/T/

The remaining 760 potential/possible locations are unbooked.

BOE Conversions

BOEs may be misleading, particularly if used in isolation. A BOE conversion
ratio of 6 Mcf: 1 Bbl is based on an energy equivalency conversion method
primarily applicable at the burner tip and does not represent a value
equivalency at the wellhead.

NON-GAAP Measures

Netback per barrel and its components are calculated by dividing revenue,
royalties, operating and sales and transportation expenses by the gross
production volume during the period. Netback per barrel is a non-GAAP measure
and it is commonly used by oil and gas companies to illustrate the unit
contribution of each barrel produced.

Unaudited Financial Information

Certain financial and operating results included in this news release such as
FD&A costs, F&D costs, recycle ratio, capital expenditures, historical cost of
undeveloped land, and production information are based on unaudited estimated
results. These estimated results are subject to change upon completion of the
audited financial statements for the year ended December 31, 2016, and changes
could be material. The Company anticipates filing its audited financial
statements and related management’s discussion and analysis for the year ended
December 31, 2016 on SEDAR on or before April 30, 2017.

Industry Metrics

This news release contains metrics commonly used in the oil and natural gas
industry. Each of these metrics is determined by the Company as set out below
or elsewhere in this news release. These metrics are “reserve replacement”,
“F&D” costs, “FD&A” costs, “recycle ratio”, and “reserve-life index”. These
metrics do not have standardized meanings and may not be comparable to similar
measures presented by other companies. As such, they should not be used to make
comparisons.

Management uses these oil and gas metrics for its own performance measurements
and to provide shareholders with measures to compare the Company’s performance
over time, however, such measures are not reliable indicators of the Company’s
future performance and future performance may not compare to the performance in
previous periods.

“F&D” costs are calculated by dividing the sum of the total capital
expenditures for the year (in dollars) by the change in reserves within the
applicable reserves category (in boe). F&D costs, including FDC, includes all
capital expenditures in the year as well as the change in FDC required to bring
the reserves within the specified reserves category on production.

“FD&A costs” are calculated by dividing the sum of the total capital
expenditures for the year inclusive of the net acquisition costs and
disposition proceeds (in dollars) by the change in reserves within the
applicable reserves category inclusive of changes due to acquisitions and
dispositions (in boe). FD&A costs, including FDC, includes all capital
expenditures in the year inclusive of the net acquisition costs and disposition
proceeds as well as the change in FDC required to bring the reserves within the
specified reserves category on production.

The Company uses F&D and FD&A as a measure of the efficiency of its overall
capital program including the effect of acquisitions and dispositions. The
aggregate of the exploration and development costs incurred in the most recent
financial year and the change during that year in estimated future development
costs generally will not reflect total finding and development costs related to
reserves additions for that year.

“Reserve replacement” is calculated by dividing the annual proved plus probable
reserve adds (in boe) by the Company’s annual production (in boe). The Company
uses this measure to determine the relative change of its reserves base over a
period of time by measuring the amount of proved reserves and proved plus
probable reserves added to a company’s reserve base during the year relative to
the amount of oil and gas produced.

“Reserve life index” or “RLI” is calculated by dividing the reserves (in boe)
in the referenced category by the latest quarter of production (in boe). The
Company uses this measure to determine how long the booked reserves will last
at current production rates if no further reserves were added.

“Recycle ratio” is calculated by dividing the operating netback (in dollars per
boe for the most recent quarter) by the FD&A costs (in dollars per boe) for the
year. The Company uses recycle ratio as an indicator of profitability of its
oil and gas activities.

– END RELEASE – 03/04/2017

COMPANY:
FOR: LEUCROTTA EXPLORATION INC.
TSX VENTURE SYMBOL: LXE

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170403CC0097

Press Release from Marketwired 1-866-736-3779

Precision Drilling Corporation 2017 First Quarter Results Conference Call and Webcast

April 3, 2017 by The Canadian Press

FOR: PRECISION DRILLING CORPORATION
TSX SYMBOL: PD
NYSE SYMBOL: PDS

Date issue: April 03, 2017
Time in: 4:10 PM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 3, 2017) – Precision Drilling
Corporation (“Precision”) (TSX:PD)(NYSE:PDS) intends to release its 2017 first
quarter results before the market opens on Monday April 24, 2017 and has
scheduled a conference call and webcast to begin promptly at 12:00 Noon MT
(2:00 p.m. ET) on the same day.

The conference call dial in numbers are 844-515-9176 or 614-999-9312
(International) or a live webcast is accessible on Precision’s website at
www.precisiondrilling.com.

An archived version of the webcast will be available for approximately 60 days.
An archived recording of the conference call will be available approximately
one hour after the completion of the call until April 26, 2017 by dialing
855-859-2056 or 404-537-3406, passcode 91818718.

About Precision

– END RELEASE – 03/04/2017

For further information:
Precision Drilling Corporation
Carey Ford
Senior Vice President & Chief Financial Officer
403.716.4566
403.716.4755 (FAX)
www.precisiondrilling.com

COMPANY:
FOR: PRECISION DRILLING CORPORATION
TSX SYMBOL: PD
NYSE SYMBOL: PDS

INDUSTRY: Energy and Utilities – Equipment, Energy and Utilities –
Oil and Gas
RELEASE ID: 20170403CC0095

Press Release from Marketwired 1-866-736-3779

Maxim Power Corp. Closes Sale of Maxim Power (USA), Inc. to Hull Street Energy

April 3, 2017 by The Canadian Press

FOR: MAXIM POWER CORP.TSX SYMBOL: MXGDate issue: April 03, 2017Time in: 11:00 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 3, 2017) – Maxim Power Corp. (“MAXIM”)
(TSX:MXG) announced today that it has closed the sale of 100% of its ownership
in…

Birchcliff Energy Ltd. Announces Increase in Ownership by Seymour Schulich

April 3, 2017 by The Canadian Press

FOR: BIRCHCLIFF ENERGY LTD.TSX SYMBOL: BIRDate issue: April 03, 2017Time in: 10:30 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 3, 2017) – Birchcliff Energy Ltd.
(“Birchcliff”) (TSX:BIR) is pleased to announce that Mr. Seymour Schulich has
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Qatar to boost production from vast underwater gas field

April 3, 2017 by The Canadian Press

DOHA, Qatar — The energy-rich Gulf nation of Qatar says it plans to boost production from a vast underwater natural gas field by 10 per cent.

State-run Qatar Petroleum said Monday the increase would give the 2022 World Cup host capacity to export some 2 billion cubic feet of gas per day from the North Field.

Qatar is a small but wealthy member of OPEC that generates most of its income from natural gas rather than crude oil. It exports the gas by chilling it to a liquefied form that can be shipped on tankers to customers around the world.

It shares control of the North Field with Iran, which lies on the other side of the Persian Gulf.

The Associated Press

AltaGas Ltd. Announces Simplified Sale Program

April 3, 2017 by The Canadian Press

FOR: ALTAGAS LTD.TSX SYMBOL: ALADate issue: April 03, 2017Time in: 8:30 AM eAttention:
CALGARY, ALBERTA–(Marketwired – April 3, 2017) – AltaGas Ltd. (“AltaGas”)
(TSX:ALA) announced today it is initiating a simplified sale program for
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Pine Cliff Energy Ltd. Announces Extension of Borrowing Base Redetermination

April 3, 2017 by The Canadian Press

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CALGARY, ALBERTA–(Marketwired – April 3, 2017) – Pine Cliff Energy Ltd. (“Pine
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Blue Sky Announces Private Placement Financing

April 3, 2017 by The Canadian Press

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Zargon Announces Completion of Redemption Auction

April 3, 2017 by The Canadian Press

FOR: ZARGON OIL & GAS LTD.
TSX SYMBOL: ZAR
TSX SYMBOL: ZAR.DB

Date issue: April 03, 2017
Time in: 7:00 AM e

Attention:

CALGARY, ALBERTA–(Marketwired – April 3, 2017) – Zargon Oil & Gas Ltd.
(“Zargon” or the “Company”) (TSX:ZAR)(TSX:ZAR.DB) announces that it has taken
up $15.56 million aggregate principal amount of its 6.00% convertible unsecured
subordinated debentures (the “Debentures”) at tender prices ranging from $890
to $1,000 per $1,000 principal amount of Debentures, for a total cash
consideration of $14.84 million, which is equivalent to an average cost of $954
per debenture. The redemption of the Debentures was completed pursuant to the
Company’s previously announced redemption of up to $19 million aggregate
principal amount of Debentures at cash prices determined by a “Dutch auction”
process (the “Redemption Auction”).

Holders of the Debentures (“Debentureholders”) had the opportunity under the
Redemption Auction to tender their Debentures until 5:00 p.m. (Eastern Time) on
March 31, 2017. A total of $15.56 million aggregate principal amount of
Debentures were properly tendered and not withdrawn under the Redemption
Auction, all of which was taken up at the respective tender price for such
Debentures. Payment of the redemption price for Debentures being redeemed will
be in cash and will be made promptly in accordance with the terms of the
indenture governing the Debentures.

As of April 1, 2017, changes to the Debentures took effect, which are more
particularly described in the Company’s information circular dated January 16,
2017 (the “Information Circular”) and as approved by the Debentureholders at a
meeting held February 14, 2017. Debentures that were not tendered and were not
redeemed pursuant to the Redemption Auction (the “Amended Debentures”) now have
an annual interest rate of 8.00%, a maturity date of December 31, 2019 and are
subject to other changes as further described in the Information Circular
(available on the Company’s SEDAR profile at www.sedar.com).

The Amended Debentures will commence trading on the Toronto Stock Exchange
under the new symbol “ZAR.DB.A” at the open of markets on April 3, 2017. After
giving effect to the Redemption Auction, there is approximately $41.94 million
aggregate principal amount of the Amended Debentures outstanding.

ADVISORS

Macquarie Capital Markets Canada Ltd. acted as exclusive financial advisor to
Zargon for this component of its strategic alternatives process.

FURTHER INFORMATION

ADVISORY ON FORWARD-LOOKING STATEMENTS

This press release contains forward-looking statements. More particularly, this
press release contains statements concerning, but not limited to: the
Redemption Auction; the expected time of payment for redeemed Debentures; and
other matters regarding the Redemption Auction. Although management believes
that the expectations reflected in the forward-looking statements are
reasonable, it cannot guarantee future results, performance or achievement
since such expectations are inherently subject to significant business,
economic, operational, competitive, political and social uncertainties and
contingencies. As a consequence, actual results may differ materially from
those anticipated in the forward looking statements. These forward-looking
statements involve substantial known and unknown risks and uncertainties,
certain of which are beyond Zargon’s control, and many factors could cause
Zargon’s actual results to differ materially from those expressed or implied in
any forward-looking statements made by the Company, including, but not limited
to: the Company and its financial position, liquidity and outlook; and other
risks and uncertainties described from time to time in the reports and filings
made with securities regulatory authorities by the Company. Readers are
cautioned that the foregoing list of important factors is not exhaustive.

– END RELEASE – 03/04/2017

For further information:
Zargon Oil & Gas Ltd.
C.H. Hansen
President and Chief Executive Officer
403-264-9992
zargon@zargon.ca
www.zargon.ca

COMPANY:
FOR: ZARGON OIL & GAS LTD.
TSX SYMBOL: ZAR
TSX SYMBOL: ZAR.DB

INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170403CC0018

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Dakota Access fight provides blueprint for pipeline protests

April 2, 2017 by The Canadian Press

BISMARCK, N.D. — Prolonged protests in North Dakota have failed to stop the flow of oil through the Dakota Access pipeline, at least for now, but they have provided inspiration and a blueprint for protests against pipelines in other states.

The months of demonstrations that sought to halt the four-state pipeline have largely died off with the February clearing of the main protest camp and the completion of the pipeline, which will soon be moving oil from North Dakota to a distribution point in Illinois.

Four Sioux tribes are still suing to try to halt the project, which they say threatens their water supply, cultural sites and religious rights. But they’ve faced a string of setbacks in court since President Donald Trump moved into the White House.

Despite the setbacks, Dakota Access protest organizers don’t view their efforts as wasted. They say the protests helped raise awareness nationwide about their broader push for cleaner energy and greater respect for the rights of indigenous people.

“The opportunity to build awareness started at Standing Rock and it’s spreading out to other areas of the United States,” said Dave Archambault, the chairman of the Standing Rock Sioux tribe, which has led the legal push to shut down the pipeline project.

As protesters left the area in southern North Dakota where the Dakota Access pipeline crosses under a Missouri River reservoir that serves as the tribes’ water supply, organizers called on them to take the fight to other parts of the country where pipelines are in the works.

The tactics used in North Dakota — resistance camps, prominent use of social media, online fundraising — are now being used against several projects. They include the Sabal Trail pipeline that will move natural gas from Alabama to Florida; the Trans-Pecos natural gas pipeline in Texas; the Diamond pipeline that will carry oil from Oklahoma to Tennessee; and the Atlantic Sunrise pipeline that will move natural gas from Pennsylvania to Virginia.

They’re also being used against projects that are still in the planning stages, including the proposed Pilgrim oil pipeline in New York and New Jersey and the proposed Bayou Bridge Pipeline in Louisiana.

Dakota Access opponents have also vowed to fight against the resurgent Keystone XL pipeline, which would move crude oil from Canada to Nebraska and on to Texas Gulf Coast refineries.

“A big part of our message was not just to nationalize the fight against Dakota Access, but to highlight regional issues that people are facing,” said Dallas Goldtooth, an organizer with the Indigenous Environmental Network. “To use our momentum.”

The influence of the Dakota Access protest is evident in various forms. For example, some who protested in North Dakota have gone to Texas and Florida to help with those demonstrations, according to Goldtooth. The Red Warrior Society, a pipeline protest group that advocated aggressive tactics in North Dakota, is promoting resistance in other states via social media.

There are nearly a dozen accounts on the GoFundMe crowdfunding site seeking money to battle the Sabal Trail and Trans-Pecos pipelines. The Society of Native Nations, which is fighting the Trans-Pecos, used the protest camp model from North Dakota to set up a camp in Texas, according to Executive Director Frankie Orona.

“I really believe this momentum is going to stay alive,” said Orona. “Standing Rock was the focal point, was the root of this movement. If we learned anything from Standing Rock, it’s the power of unity. It wasn’t one (tribal) nation — it was more than 400.”

Hundreds, and sometimes thousands, of Dakota Access opponents congregated at the main protest camp for half a year, often clashing with police to draw attention to their cause. More than 750 people were arrested between early August and late February, when the camp was closed in advance of spring flooding season.

The prolonged protest garnered widespread and consistent attention on social media, and it has filtered down, to some degree, to the pipeline protests elsewhere. That has elevated activists’ concerns from local demonstrations to a national stage, according to Brian Hosmer, an associate professor of Western American history at the University of Tulsa.

“Social media makes it more difficult to shut off the camera,” he said. “In some way, they’re their own reporters and they don’t need the networks to report it. Social media connects the tribe; it now connects all of these separate groups.”

For now, the energy industry and its allies say they’re unconcerned.

The Dakota Access movement wrote the new playbook for pipeline opponents, but it might be less effective under Trump, said Craig Stevens, spokesman for the MAIN Coalition, a group of agriculture, business and labour entities that long spoke in favour of the pipeline. Trump approved its completion shortly after taking office and he has taken other steps favourable to the fossil fuel industry while rolling back Obama-era environmental protections.

U.S. Rep. Kevin Cramer, a North Dakota Republican who has advised Trump on energy issues, said pipeline developers have learned to prepare for resistance, and he thinks the anti-pipeline movement will fade if protesters fail to achieve their goals and get discouraged.

Juliana Schwartz, senior campaigner for Change.org, which helps people and groups advance causes, disagrees, saying the environmental protest movement appears to be strong. A “people against pipelines” page on the group’s website recently listed 16 petitions related to energy projects — mostly pipelines — in more than half a dozen states, with nearly 725,000 supporters.

“The broader movement to stop resource extraction has taken inspiration from (Dakota Access),” Schwartz said. “I think we can expect to see this trend continue as more and more communities feel that their safety and health is under threat due to the president’s support of the fossil fuel industry over marginalized communities.”

___

Contributing to this story were Associated Press writers Justin Juozapavicius in Tulsa, Oklahoma; David Warren in Dallas; Dave Kolpack in Fargo, North Dakota; and Ken Miller in Oklahoma City.

___

Follow Blake Nicholson on Twitter at: https://twitter.com.NicholsonBlake

Blake Nicholson, The Associated Press

Minister: Iraq to boost crude oil production by year’s end

April 2, 2017 by The Canadian Press

BAGHDAD — Iraq’s oil minister said on Sunday that his country plans to increase daily crude oil production to 5 million barrels by the end of this year, up from the current rate of about 4.4 million barrels per day, to secure sorely needed cash for its ailing economy.

Iraq, where oil revenues make up nearly 95 per cent of the budget, has been reeling under an economic crisis since 2014, when oil prices began their descent from a high of above $100 a barrel. The Islamic State group’s onslaught, starting in 2014, has exacerbated the situation — forcing Iraq to divert much of its resources to a long and costly war.

Addressing an energy conference in Baghdad, Oil Minister Jabar Ali Al-Luaibi didn’t give details on which of the country’s oil fields would supply the increased output.

Late last year, Iraq joined a deal by OPEC and non-OPEC members to lower production for six months by 1.8 million barrels a day in order to prop up global oil prices. The mutual production decrease began on Jan. 1. Iraq’s share in the deal is to reduce output by 210,000 barrels a day to 4.351 million barrels.

“There are positive elements in that deal and we achieved a lot of its targets,” al-Luaibi told reporters on the sideline of the conference. “Work and co-operation are underway … to reach the 1.8 (million barrels a day) reduction,” he added, without divulging whether Iraq is going to support an extension to that deal.

OPEC Secretary General, Mohammed Barkindo, said the compliance among the participants was 86 per cent in January and 94 per cent in February. Barkindo told reporters that OPEC members would consider whether to extend the production decrease agreement at a meeting next month.

The deal propped up the crude price to around $50 per barrel.

Iraq holds the world’s fourth-largest oil reserves. This year, it added 10 billion barrels, bringing its total reserves up to 153.1 billion barrels.

Al-Luaibi also said that more 15 billion barrels are planned to be added by 2018.

Iraq’s 2017 budget stands at about 100.67 trillion Iraqi dinars, or nearly $85.17 billion, running with a deficit of 21.65 trillion dinars, or about $18.32 billion. That’s based on an estimated oil price of $42 per barrel and daily export capacity of 3.75 million barrels.

Iraq is also grappling with a major humanitarian crisis. The U.N. estimates that more than 3 million people have been forced from their homes since 2014. It also faces growing dissatisfaction among residents of areas recaptured from IS who have had their properties demolished and suffer from scarce public services.

Sinan Salaheddin, The Associated Press

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