FOR: PRAIRIE PROVIDENT RESOURCES INC.
TSX SYMBOL: PPR
Date issue: March 31, 2017
Time in: 7:00 AM e
Attention:
CALGARY, ALBERTA–(Marketwired – March 31, 2017) – Prairie Provident Resources
Inc. (“Prairie Provident”, “PPR” or the “Company”) (TSX:PPR) is pleased to
announce its operating and financial results for the three months and year
ended December 31, 2016, and to provide an operational update. PPR’s audited
consolidated financial statements (“Annual Financial Statements”) and related
Management’s Discussion and Analysis (“MD&A”) for the three months and year
ended December 31, 2016 are available on its website and filed on SEDAR.
PPR is a light and medium oil-weighted growth company, formed through the
business combination of Lone Pine Resources Inc. and Lone Pine Resources Canada
Ltd. (now Prairie Provident Resources Canada Ltd.) (collectively, “Lone Pine”)
and Arsenal Energy Inc. (“Arsenal”) which was effected on September 12, 2016
(the “Arsenal Acquisition”). Results for the fourth quarter of 2016 reflect the
first full quarter of operations as PPR.
Prairie Provident’s Annual Financial Statements present the results for the
historical Lone Pine properties for the period up to September 12, 2016 and for
the combination of Lone Pine and Arsenal after September 12, 2016. This is a
significant factor in understanding the year-over-year and quarter-over-quarter
financial results of Prairie Provident. This news release contains
forward-looking information and statements and non-IFRS measures. Readers are
cautioned that the news release should be read in conjunction with the
Company’s disclosures under the headings “Forward-Looking Statements” and
“Non-IFRS Measures” included at the end of this news release.
FOURTH QUARTER 2016 HIGHLIGHTS
/T/
— Achieved average fourth quarter 2016 production of 4,845 boe/d (58%
liquids), a 90% increase over the same period of 2015 due to
approximately 1,650 boe/d of production additions related to 16 wells in
Wheatland and approximately 1,300 boe/d of production from Arsenal’s
properties, and exited 2016 with average daily production of
approximately 5,500 boe/d (56% liquids);
— Generated fourth quarter adjusted funds from operations of $7.1 million
($0.07 per diluted share), up 1% from the same period in 2015, as
incremental production from the new Wheatland wells and a full quarter
of production from Arsenal were offset by lower realized gains on
derivative instruments;
— Operating netbacks (before realized hedging gains) for the quarter were
$19.26/boe, 5% higher than the fourth quarter of 2015 due to
improvements in realized prices and reductions in per boe operating
costs. Operating netbacks (after realized hedging gains) for the quarter
were $22.32/boe, lower than the $39.31/boe generated in the same period
of the prior year due to a $17.91/boe reduction in realized hedging
gains;
— Capital expenditures in the quarter totaled $11.9 million, which were
primarily directed to the ongoing drilling program at Wheatland. Three
wells were drilled at Wheatland during the fourth quarter (100% success
rate) and eight wells were brought on-stream, including seven wells
drilled in the third quarter and one well drilled in the fourth quarter;
— Continued to enhance drilling and completion techniques, achieving all-
in per well costs of approximately $1.6 million to drill, complete,
equip and tie-in; and
— Maintained financial flexibility and a strong balance sheet with year-
end bank debt of $15.5 million or 28% drawn on the Company’s $55 million
credit facility (together with outstanding letters of credit, $20.9
million or 38% of the credit facility was utilized).
/T/
2016 ANNUAL HIGHLIGHTS
/T/
— Full-year 2016 production of 3,680 boe/d (58% liquids) increased 39% on
a year-over-year basis with the primary variances being production
additions from Wheatland (approximately 1,230 boe/d) and the Arsenal
Acquisition (approximately 400 boe/d);
— Capital expenditures totaled $34.9 million, comprised of $31.2 million
invested in the Wheatland drilling program and $2.3 million directed to
the second phase of the Evi Waterflood project;
— Reported an operating netback (after realized hedging gains) of
$17.95/boe for 2016, a 54% decrease from 2015 due to lower realized
gains on derivative instruments and lower realized prices;
— Generated full-year adjusted funds from operations of $13.3 million
($0.14 per diluted share), a 50% decrease on a year-over-year basis due
primarily to lower operating netbacks, partially offset by higher
production and lower G&A expenses;
— Issued 5,465,000 common shares as Canadian exploration expenses (“CEE”)
flow-through shares at $0.85 per share and 375,000 Canadian development
expenses (“CDE”) flow-through common shares at $0.80 per share in
December 2016 for total gross proceeds of $4.95 million; and
— Subsequent to year-end, acquired high quality light oil assets in the
Greater Red Earth area for cash consideration of $41.0 million (the “Red
Earth Acquisition”). The Company also issued CEE flow-through shares and
common shares and warrants for total gross proceeds of $8.0 million and
the borrowing capacity on its credit facility was increased to $65
million.
/T/
FINANCIAL AND OPERATING HIGHLIGHTS
/T/
Three Months Ended Year Ended
December 31 December 31
——————————————————————-
——————————————————————-
($000s except per
unit amounts) 2016 2015 2016 2015
——————————————————————-
——————————————————————-
Financial
Oil and natural gas
revenue 17,060 8,783 42,748 39,335
Net loss (8,782) (15,390) (60,396) (59,894)
Per share – basic
& diluted(1) (0.09) (0.16) (0.62) (0.61)
Adjusted funds from
operations(2) 7,107 7,007 13,259 26,382
Per share – basic
& diluted(3) 0.07 0.07 0.14 0.27
Net capital
expenditures 11,918 9,809 34,875 24,627
——————————————————————-
——————————————————————-
Production Volumes
Crude oil (bbls/d) 2,653 1,799 2,012 1,820
Natural gas (Mcf/d) 12,300 4,130 9,253 4,577
Natural gas liquids
(bbls/d) 142 63 126 69
——————————————————————-
Total (boe/d) 4,845 2,550 3,680 2,652
——————————————————————-
% Liquids 58% 73% 58% 71%
——————————————————————-
——————————————————————-
——————————————————————-
——————————————————————-
Average Realized
Prices
Crude oil ($/bbl) 54.28 46.58 46.75 51.24
Natural gas ($/Mcf) 3.09 2.56 2.21 3.01
Natural gas liquids
($/bbl) 24.49 17.08 17.91 10.76
——————————————————————-
Total ($/boe) 38.27 37.44 31.74 40.64
——————————————————————-
——————————————————————-
Operating Netback
($/boe)(4)
Realized price 38.27 37.44 31.74 40.64
Royalties (5.09) (3.18) (3.63) (2.26)
Operating costs (13.92) (15.92) (17.39) (16.49)
——————————————————————-
Operating netback 19.26 18.34 10.72 21.89
Realized gains on
derivative
instruments 3.06 20.97 7.23 17.34
——————————————————————-
Operating netback,
after realized
gains on derivative
instruments 22.32 39.31 17.95 39.23
——————————————————————-
——————————————————————-
Notes:
(1)(3) As the historical financial statements were prepared on a combined
and consolidated basis (see note 3(a) to the Annual Financial
Statements), it is not possible to measure per share amounts until
subsequent to the closing of the Arsenal Acquisition on September
12, 2016 when Lone Pine and Arsenal were brought under a common
parent entity. The Company calculated per share information for the
current and historical periods by assuming that the common shares
issued upon the closing of the Arsenal Acquisition at September 12,
2016 were outstanding since the beginning of the period.
(2)(4) Adjusted funds from operations and operating netback are non-IFRS
measures and are defined below under “Other Advisories”.
—————————————————————————-
—————————————————————————-
As at As at
Capital Structure December 31, December 31,
($000s) 2016 2015
—————————————————————————-
Working capital (deficit)(1) (4,380) 12,268
Long-term debt (15,047) –
————————-
Total net debt(2) (19,427) 12,268
Current debt capacity(3) 34,117 45,529
Common shares outstanding (in millions)(4) 104.2 N/A
—————————————————————————-
—————————————————————————-
Notes:
(1) Working capital (deficit) is a non-IFRS measure (see Other Advisories
below) calculated as current assets less current liabilities excluding
the current portion of derivative instruments, the current portion of
decommissioning liabilities and flow-through share premium.
(2) Net debt is a non-IFRS measure (see Other Advisories below),
calculated by adding working capital (deficit) and long-term debt.
(3) Current debt capacity reflects the credit facility of $55 million at
December 31, 2016 and of $50 million at December 31, 2015.
(4) As historical financial statements were prepared on a combined and
consolidated basis (see note 3(a) to the Annual Financial Statements),
common shares outstanding is not a relevant measure until subsequent
to the closing of the Arsenal Acquisition on September 12, 2016 when
Lone Pine and Arsenal were brought under a common parent entity.
—————————————————————————-
Three months ended Year ended
December 31 December 31
—————————————————————————-
2016 2015 2016 2015
—————————————————————————-
Drilling Activity
Gross wells 3 2 14 4
Working interest wells 2.95 1.95 12.65 3.95
Success rate, net wells (%) 100 100 100 100
—————————————————————————-
—————————————————————————-
/T/
YEAR IN REVIEW
In September 2016, Lone Pine and Arsenal completed a business combination to
form Prairie Provident. Upon completion, Lone Pine securityholders held
approximately 77% of the fully diluted PPR shares, while former Arsenal
securityholders held approximately 23%. With a larger operational footprint and
increased access to capital, PPR commenced a variety of initiatives:
/T/
— Integrated the Arsenal team and grew its production profile, while
maintaining similar G&A cost structure, which resulted in a reduction of
G&A per boe by 37% when compared to 2015;
— Achieved organic production additions at Wheatland of 1,650 boe/d,
bringing total current production at the play to approximately 2,500
boe/d; and
— Grew Evi from 1,200 boe/d to approximately 2,500 boe/d through
synergistic acquisitions. Subsequent to the year-end of 2016, PPR
acquired assets in the Greater Red Earth area for cash consideration of
$41.0 million and issued CEE flow-through shares and common shares and
warrants for total gross proceeds of $8.0 million. Additionally, the
Company’s credit facility was amended to increase the borrowing capacity
to $65 million.
/T/
OPERATIONS UPDATE
Wheatland, AB
Prairie Provident successfully completed its 2016 capital program spending
$31.2 million in this core area, within capital expenditure guidance provided
in the third quarter of 2016. The 2016 Wheatland capital program included a
total of 14 gross (12.65 net) wells drilled with 12 brought on-stream. The
remaining two wells drilled and completed in 2016 that were not on production
by the end of the year were brought on-stream in February 2017, bringing the
total number of developed wells in the area to 18. During the fourth quarter of
2016, average sales volumes in the Wheatland area were approximately 1,797 boe
per day (30% light/medium oil), which is expected to increase in the first
quarter 2017 due to new volumes coming on stream late in 2016 and early 2017.
Our development across this region has been focused primarily in the northern
and central region of the play and has yielded three significant discoveries.
Our focus for 2017 will be on the multiple follow-up locations across the
fairway, while future exploration will be tested over the next two years in the
southern sections. Our 2017 capital program contemplates the drilling of up to
14 wells in the Wheatland area and the Company has already drilled and cased
the first four Ellerslie wells from our 2017 budget.
Prairie Provident continues to improve its drilling cycle times and overall
costs at Wheatland by pad drilling and utilizing a mono-bore drilling design,
which has significantly reduced surface costs, lowered the environmental
footprint and increased the anticipated return on capital. These design
optimizations combined with lower service costs have reduced drilling times
from an average of 13 days down to 8.5 days, while all-in costs have been
reduced significantly to approximately $1.6 million per well, down over 40%
from $2.7 million per well one year ago.
Princess, AB
At Princess, two discovery wells are awaiting tie-in that have cumulatively
tested at more than 400 bbl/d of oil, while a total of 15 additional locations
have been identified in the Detrital and Glauconite formations. During the
three months and year ended December 31, 2016, our Princess properties produced
average sales volumes of approximately 480 boe per day (83% medium oil) and 143
boe per day (83% medium oil), respectively. Prairie Provident plans to drill up
to 8 wells at Princess in 2017.
Evi, AB
During the three months and year ended December 31, 2016, our Evi properties
produced average sales volumes of approximately 1,458 boe per day (97% light
oil) and 1,323 boe per day (95% light oil), respectively. The Evi properties
provide the Company with a stable cash flow base that complements its
development programs, while the economics (rates of return, payback and recycle
ratio) remain very robust, even at current strip pricing. PPR believes that the
waterflood program will continue to stabilize production from this play and
enhance long-term recoveries.
The Company currently has nine (9.0 net) injection wells (eight horizontals and
one vertical) in operation. Initial results from the program correspond with an
independent study conducted in 2015 on the feasibility of a full-field
waterflood program. An additional four injector conversions are planned for
2017, and over the long-term, our ‘full field low case scenario’ contemplates
14 producing wells to be converted to injection wells for total future costs of
approximately $13.5 million.
Subsequent to year-end, the Company closed the Red Earth Acquisition which is
complementary to existing operations at Evi. The transaction added
approximately 1,100 boe/d (98% oil and liquids), provides for synergistic
opportunities to reduce area estimated operating costs by $2 million per year
(or $2.00/boe), and optimize waterflood expansion with seven prospective
projects.
2017 OUTLOOK AND GUIDANCE
PPR’s capital allocation process considers numerous operational dynamics and
financial factors. We incorporate competitive elements into the process such
that projects with the highest rates of return are given top priority and
growth on a per share basis is a central tenet of the planning process. Through
2017, we will continue to focus on improving corporate netbacks by targeting
the production of higher value streams (oil / condensate rich liquids) and
enhancing our capital efficiencies through various operational initiatives such
as pad drilling and operating in areas with underutilized infrastructure
capacity. Given the continued volatility in commodity prices, the Company
remains focused on capital management, targeting a debt to EBITDAX ratio of 1.0
time. We will continue to add positions to our hedge book (currently covering
63% of 2017 forecast base oil production (net of royalties) at $69.51/bbl) to
provide downside price protection and support our adjusted funds from
operations through 2018 and beyond.
In connection with closing the Red Earth Acquisition in March of 2017, our
credit facility was amended upward and the Company now has a total borrowing
capacity of $65 million, comprised of a $55 million syndicated revolving credit
facility and a $10 million operating facility. This increased financial
flexibility, combined with forecasted 2017 adjusted funds from operations of
$31 – 35 million, will allow the Company to fund a $25 – 35 million capital
budget. Our 2017 budget is scalable depending on commodity prices, with excess
adjusted funds from operations directed to debt repayment.
An active drilling program in 2017 is expected to position the Company to
deliver production per share growth of approximately 55% and generate strong
rates of return on its assets at current commodity prices. Our inventory of
conventional horizontal and vertical wells provides the Company with over five
years of drilling to underpin profitable per share growth. Waterflood
initiatives are expected to lower corporate decline rates and stabilize
production levels over the medium and longer term. Prairie Provident is
positioned to execute a profitable organic growth program through 2017.
The 2017 program assumes price forecasts of USD$54.00/bbl WTI, CAD$2.75/GJ
AECO, and a Canadian/US dollar exchange rate of $0.76 and anticipates the
following:
/T/
Targets
Exit production (boe/d) 7,500 – 8,000
Annual production (boe/d) (1) 6,100 – 6,600
% of liquids 60% – 65%
Operating expenses ($/boe) 16.00 – 17.00
Operating netback ($/boe) (2) 16.00 – 17.00
Operating netback, after realized gains from derivative
instruments ($/boe) (2) 17.00 – 18.00
Royalties (%) 16%
G&A, excluding stock-based compensation and net of capitalized
G&A ($/boe) 3.00 – 4.00
Capital expenditures ($millions) 25 – 35
(1) Includes production from the Red Earth Acquisition since March 22,
2017, the closing date of the transaction.
(2) Operating netback is a non-IFRS measure (see “Other Advisories”
below).
/T/
Over the last several quarters, various positive indicators have been observed
within the Canadian energy industry which has given us the confidence to
continue executing our returns-based growth strategy and make the accretive Red
Earth Acquisition to expand our asset portfolio. We recognize that the macro
environment remains challenging with continued uncertainty around OPEC
production cuts, the stability of oil prices, and the potential implementation
of various policies by the new administration in the United States. Against
this backdrop, we are committed to pursue the generation of positive returns
for shareholders while pursuing growth.
From a capital markets standpoint, we remain focused on increasing exposure of
the Company to the investment community and enhancing the trading liquidity of
our shares; however, we are firmly of the belief that continued operational
execution, growth on a per share basis, and prudently managing our balance
sheet will ultimately be the key drivers towards increasing shareholder value.
ABOUT PRAIRIE PROVIDENT:
Prairie Provident is a Calgary-based company engaged in the exploration and
development of oil and natural gas properties in Alberta. The Company’s
strategy is to grow organically in combination with accretive acquisitions of
conventional oil prospects, which can be efficiently developed. Prairie
Provident’s operations are primarily focused at Wheatland and Princess in
Southern Alberta targeting the Ellerslie and the Lithic Glacu formations, along
with an early stage waterflood project at Evi in the Peace River Arch. Prairie
Provident protects its balance sheet through an active hedging program and
manages risk by allocating capital to opportunities offering maximum
shareholder returns.
FORWARD-LOOKING STATEMENTS
This news release contains certain forward-looking information and statements
within the meaning of applicable Canadian securities laws. Statements involving
forward-looking information relate to future performance, events or
circumstances, and are based upon internal assumptions, plans, intentions,
expectations and beliefs. All statements other than statements of current or
historical fact constitute forward-looking information. Forward-looking
information is typically, but not always, identified by words such as
“anticipate”, “believe”, “expect”, “intend”, “plan”, “budget”, “forecast”,
“target”, “estimate”, “propose”, “potential”, “project”, “continue”, “may”,
“will”, “should” or similar words suggesting future outcomes or events or
statements regarding an outlook. In particular, but without limiting the
foregoing, this news release contains forward-looking information and
statements pertaining to the following: projected capital expenditure plans,
production and product mix, production growth expectations, development and
exploration plans at Wheatland, Princess and Evi (including with respect to
numbers of wells at Wheatland and Princess and Evi waterflood activities and
expectations), opportunities for operating cost reductions in the Greater Red
Earth area, continued focus on corporate netbacks and capital efficiency and
anticipated activities in furtherance thereof, future hedging arrangements,
projected annual and exit production, operating costs, operating netback,
royalties, G&A expenses, capital expenditures and adjusted funds from
operations of Prairie Provident for 2017 and beyond, assumptions as to future
commodity prices, its risk management plans for 2017 and beyond, use of excess
funds from operations for debt repayment, per share production growth, drilling
inventory numbers, expected benefits fo waterflood initiatives, view on
potential benefits from the Red Earth Acquisition and future merger and
acquisition activities.
The forward-looking information and statements contained in this news release
reflect material factors and expectations and assumptions of Prairie Provident
including, without limitation: commodity prices and foreign exchange rates for
2017 and beyond; the timing and success of future drilling, development and
completion activities (and the extent to which the results thereof meet
Management’s expectations); the continued availability of financing (including
borrowings under the Company’s credit facility) and cash flow to fund current
and future expenditures, with external financing on acceptable terms; future
capital expenditure requirements and the sufficiency thereof to achieve the
Company’s objectives; the performance of both new and existing wells;
production from the Red Earth Acquisition and capital and operating costs in
respect thereof; the timely availability and performance of facilities,
pipelines and other infrastructure in areas of operation; the geological
characteristics and quality of Prairie Provident’s properties and the
reservoirs in which the Company conducts oil and gas activities (including
field production and decline rates); successful integration of the Red Earth
Acquisition assets into the Company’s operations; the successful application of
drilling, completion and seismic technology; future exploration, development,
operating, transportation, royalties and other costs; the Company’s ability to
economically produce oil and gas from its properties and the timing and cost to
do so; the predictability of future results based on past and current
experience; prevailing weather conditions; prevailing legislation and
regulatory requirements affecting the oil and gas industry (including royalty
regimes); the timely receipt of required regulatory approvals; the availability
of capital, labour and services on timely and cost-effective basis; the
creditworthiness of industry partners and the ability to source and complete
acquisitions; and the general economic, regulatory and political environment in
which the Company operates. Prairie Provident believes the material factors,
expectations and assumptions reflected in the forward-looking information and
statements are reasonable but no assurance can be given that these factors,
expectations and assumptions will prove to be correct.
All information and statements that are in the nature of a financial outlook
are forward-looking statements as they relate to prospective financial
performance, financial position or cash flows based on assumptions about future
economic conditions and courses of action. Financial outlook information in
this news release includes statements regarding future funds flow from
operations and operating netback, which are subject to the assumptions, risk
factors, limitations and qualifications set forth above. All financial outlook
information is made as of the date of this news release and is provided for the
sole purpose of describing the Company’s internal expectations on cash flows
for 2017, and should not be used, and may be inappropriate for, any other
purpose.
Although Prairie Provident believes that the expectations and assumptions upon
which the forward-looking information in this news release is based are
reasonable based on currently available information, undue reliance should not
be placed on such information, which is inherently uncertain, relies on
assumptions and expectations, and is subject to known and unknown risks,
uncertainties and other factors, both general and specific, many of which are
beyond the Company’s control, that may cause actual results or events to differ
materially from those indicated or suggested in the forward-looking
information. Prairie Provident can give no assurance that the forward-looking
information contained herein will prove to be correct or that the expectations
and assumptions upon which they are based will occur or be realized. These
include, but are not limited to: risks inherent to oil and gas exploration,
development, exploitation and production operations and the oil and gas
industry in general, including geological, technical, engineering, drilling,
completion, processing and other operational problems and potential delays,
cost overruns, production or reserves loss or reduction in production, and
environmental, health and safety implications arising therefrom; uncertainties
associated with the estimation of reserves, production rates, product type and
costs; adverse changes in commodity prices, foreign exchange rates or interest
rates; the ability to access capital when required and on acceptable terms; the
ability to secure required services on a timely basis and on acceptable terms;
increases in operating costs; environmental risks; changes in laws and
governmental regulation (including with respect to royalties, taxes and
environmental matters); adverse weather or break-up conditions; competition for
labour, services, equipment and materials necessary to further the Company’s
oil and gas activities; and changes in plans with respect to exploration or
development projects or capital expenditures in respect thereof. These and
other risks are discussed in more detail in the Company’s current annual
information form and other documents filed by it from time to time with
securities regulatory authorities in Canada, copies of which are available
electronically under Prairie Provident’s issuer profile on the SEDAR website at
www.sedar.com and on the Company’s website at www.ppr.ca. This list is not
exhaustive.
The forward-looking information and statements contained in this news release
speak only as of the date of this news release, and Prairie Provident assumes
no obligation to publicly update or revise them to reflect new events or
circumstances, or otherwise, except as may be required pursuant to applicable
laws. All forward-looking information and statements contained in this news
release are expressly qualified by this cautionary statement.
OTHER ADVISORIES
The oil and gas industry commonly expresses production volumes and reserves on
a “barrel of oil equivalent” basis (“boe”) whereby natural gas volumes are
converted at the ratio of six thousand cubic feet to one barrel of oil. The
intention is to sum oil and natural gas measurement units into one basis for
improved analysis of results and comparisons with other industry participants.
A boe conversion ratio of six thousand cubic feet to one barrel of oil is based
on an energy equivalency conversion method primarily applicable at the burner
tip. It does not represent a value equivalency at the wellhead nor at the plant
gate, which is where Prairie Provident sells its production volumes. Boes may
therefore may be a misleading measure, particularly if used in isolation. 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 ratio of
6:1, utilizing a 6:1 conversion ratio may be misleading as an indication of
value.
Non-IFRS Measures
The Company uses certain terms in this news release and within the MD&A that do
not have a standardized or prescribed meaning under International Financial
Reporting Standards (IFRS), and, accordingly these measurements may not be
comparable with the calculation of similar measurements used by other
companies. For a reconciliation of each non-IFRS measure to its nearest IFRS
measure, please refer to the “Non-IFRS Measures” section in the MD&A. Non-IFRS
measures are provided as supplementary information by which readers may wish to
consider the Company’s performance, but should not be relied upon for
comparative or investment purposes. The non-IFRS measures used in this news
release are summarized as follows:
Working Capital – Working capital (deficit) is calculated as current assets
less current liabilities excluding the current portion of derivative
instruments, the current portion of decommissioning liabilities and
flow-through share premium. This measure is used to assist management and
investors in understanding liquidity at a specific point in time. The current
portion of derivatives instruments is excluded as management intends to hold
derivative contracts through to maturity rather than realizing the value at a
point in time through liquidation. The current portion of decommissioning
expenditures is excluded as these costs are discretionary and the current
portion of flow-through share premium liabilities are excluded as it is a
non-monetary liability.
Net Debt – Net debt is defined as long-term debt plus working capital surplus
or deficit. Net debt is commonly used in the oil and gas industry for assessing
the liquidity of a company.
Operating Netback – Operating netback is a non-IFRS measure commonly used in
the oil and gas industry. This measurement assists management and investors to
evaluate the specific operating performance at the oil and gas lease level.
Operating netbacks included in this news release were determined by taking (oil
and gas revenues less royalties less operating costs) divided by gross working
interest production. Operating netback, including realized commodity (loss) and
gain, adjusts the operating netback for only realized gains and losses on
derivative instruments.
Adjusted Funds from Operations – Adjusted funds from operations is calculated
based on cash flow from operating activities before changes in non-cash working
capital, transaction costs, restructuring costs, decommissioning expenditures
and other non-recurring items. Management believes that such a measure provides
an insightful assessment of Prairie Provident’s operation performance on a
continuing basis by eliminating certain non-cash charges and charges that are
non-recurring and utilizes the measure to assess its ability to finance
operating activities, capital expenditures and debt repayments. Adjusted funds
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.
– END RELEASE – 31/03/2017
For further information:
Prairie Provident Resources Inc.
Tim Granger
President and Chief Executive Officer
(403) 292-8110
tgranger@ppr.ca
www.ppr.ca
COMPANY:
FOR: PRAIRIE PROVIDENT RESOURCES INC.
TSX SYMBOL: PPR
INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20170331CC0010
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