FOR: CORRIDOR RESOURCES INC.
TSX SYMBOL: CDH
Date issue: March 30, 2017
Time in: 7:47 PM e
Attention:
HALIFAX, NOVA SCOTIA–(Marketwired – March 30, 2017) – Corridor Resources Inc.
(TSX:CDH) (“Corridor” or the “Company”) announced today its 2016 year-end
financial results and reserves evaluations. Corridor’s annual financial
statements, annual management’s discussion and analysis and Annual Information
Form for the year ended December 31, 2016 have been filed on SEDAR at
www.sedar.com and are available on Corridor’s website at www.corridor.ca. All
amounts referred to in this press release are in Canadian dollars unless
otherwise stated.
Year End Financial Results
The following table provides a summary of Corridor’s financial and operating
results for the three and twelve months ended December 31, 2016 with
comparisons to the three and twelve months ended December 31, 2015.
Selected Financial Information
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—————————————————————————-
Three months ended Twelve months ended
December 31 December 31
thousands of dollars
except per share
amounts 2016 2015 2016 2015
—————————————————————————-
Sales $ 2,356 $ 3,630 $ 13,541 $ 15,876
Net income (loss) $ 12,316 $ (33,952) $ (29,291) $ (31,879)
Net income (loss)
per share – basic $ 0.139 $ (0.383) $ (0.330) $ (0.360)
Net income (loss)
per share – diluted $ 0.139 $ (0.383) $ (0.330) $ (0.360)
Cash flow from
operations(1) $ 722 $ 984 $ 4,307 $ 6,726
Capital expenditures $ 175 $ 163 $ 420 $ 937
Total assets $ 104,618 $ 133,066 $ 104,618 $ 133,066
—————————————————————————-
—————————————————————————-
(1) Cash flow from operations is a non-IFRS measure. Cash flow from
operations represents net earnings adjusted for non-cash items including
depletion, depreciation and amortization, deferred income taxes, share-based
compensation and other non-cash expenses. See “Non-IFRS Financial Measures”
in Corridor’s management’s discussion and analysis for the year ended
December 31, 2016.
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2016 Highlights
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— The average daily natural gas production increased to 5.8 mmscfpd in
2016 from 4.0 mmscfpd in 2015 as a result of management’s decision to
shut-in most of the McCully wells from May 1, 2015 to October 29, 2015
as opposed to only partially shutting-in its natural gas production
between September 2016 and November 2016. Management had determined in
each of 2015 and 2016 to selectively shut-in its producing natural gas
wells in the McCully Field as a long term optimization strategy to take
advantage of the expected significant differential in the sale price of
natural gas at the Algonquin city-gates (“AGT”) for the summer/fall
relative to the winter.
— Corridor entered into a forward sale agreement from December 1, 2016 to
March 31, 2017 for an average of 4,755 mmbtupd of natural gas
production. The forward sale volumes were based on AGT pricing but
subject to lower transportation costs, resulting in an estimated
increase of approximately $800 thousand of cash flow from operations
over the term of the forward sale agreement.
— As part of its optimization strategy and to mitigate the risks
associated with the volatility of natural gas prices, Corridor entered
into the following financial hedges; 2,500 mmbtupd of natural gas
production at a fixed price of $US6.50/mmbtu for the period from
December 1, 2016 to March 31, 2017; 1,000 mmbtupd at a fixed price of
$US7.30/mmbtu for the period from January 1, 2017 to February 28, 2017,
and 1,000 mmbtupd at a fixed price of $US9.55/mmbtu for January 2017.
— In its reserves report dated March 1, 2017 in respect of the McCully
Field in New Brunswick effective as at December 31, 2016 (“2016 GLJ
Reserves Report”), GLJ Petroleum Consultants Ltd. (“GLJ”) increased the
estimate of future natural gas revenues due to lower future
transportation costs expected as a result of an anticipated increase in
the Company’s sales to the local Maritimes market as opposed to the New
England market. As a result, the net present value of proved plus
probable reserves before income taxes discounted at 10% increased by 16%
to $54.1 million.
— As at December 31, 2016, Corridor had cash and cash equivalents of
$27,272 thousand, net working capital of $29,365 thousand and no
outstanding debt.
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Financial Summary for 2016
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— Natural gas sales for 2016 decreased to $12,596 thousand from $15,086
thousand for 2015 due to the decrease in the average natural gas price
to $5.96/mscf in 2016 from $10.23/mscf in 2015, partially offset by the
increase in the average daily natural gas production to 5.8 mmscfpd in
2016 from 4.0 mmscfpd in 2015.
— Cash flow from operations decreased to $4,307 thousand for the year
ended December 31, 2016 from $6,726 thousand for the year ended December
31, 2015 due to the lower natural gas sales.
— Net general and administrative expenses returned to a normal level in
2016 decreasing to $2,969 thousand from $4,175 thousand in 2015 due
mostly to the costs associated with the establishment of the New
Brunswick Responsible Energy Development Alliance in 2015 and to lower
salary expenses in 2016 following a reduction in the personnel of the
Company in Q2 2015.
— The Company recognized impairment losses of $15.7 million for the year
ended December 31, 2016 which are the result of an initial impairment
loss of $28.4 million recognized in Q2 2016 following the announcement
by the Government of New Brunswick on May 27, 2016 of its decision to
continue a moratorium on hydraulic fracturing for an indefinite period
resulting in a material reduction in the Company’s undeveloped reserves.
However, this impairment was partially offset by a reversal of
impairment loss of $12.7 million in Q4 2016 due to an increase in the
2016 GLJ Reserves Report of the estimated future natural gas revenues.
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Q4 2016 Netback Analysis
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—————————————————————————-
Three months ended Twelve months ended
December 31 December 31
thousands of dollars
except $/mscf 2016 2015 2016 2015
—————————————————————————-
Natural gas sales $2,199 $ 3,433 $ 12,596 $ 15,086
Other revenues 157 197 945 790
Realized financial
derivatives loss (121) – (121) –
Royalty expense (54) (70) (276) (371)
Transportation
expense (239) (931) (3,443) (2,781)
Production expense (616) (785) (2,421) (2,428)
—————————————————————————-
Field operating
netback $ 1,326 $ 1,844 $ 7,280 $ 10,296
—————————————————————————-
Natural gas
production per day
(mmscfpd) 3.0 5.3 5.8 4.0
Barrels of oil
equivalent per day
(boepd) 505 890 963 673
Average natural gas
price ($/mscf) $ 7.88 $ 6.99 $ 5.96 $ 10.23
Natural gas revenues
($/boe) $ 47.28 $ 41.92 $ 35.74 $ 61.39
Other revenues
($/boe) 3.37 2.41 2.68 3.22
Realized financial
derivatives
loss($/boe) (2.60) – (0.34) –
Royalty expense
($/boe) (1.15) (0.86) (0.78) (1.51)
Transportation
expense ($/boe) (5.15) (11.37) (9.77) (11.32)
Production expense
($/boe) (13.25) (9.59) (6.87) (9.88)
—————————————————————————-
Field operating
netback ($/boe) $ 28.50 $ 22.51 $ 20.66 $ 41.90
General and
administrative
expenses ($/boe) (15.14) (12.10) (8.43) (16.99)
Interest, foreign
exchange and other
($/boe) 2.16 1.61 (0.01) 2.46
—————————————————————————-
Cash flow from
operations netback
($/boe) $ 15.52 $ 12.02 $ 12.22 $ 27.37
—————————————————————————-
—————————————————————————-
— Corridor’s cash flow from operations netback for Q4 2016 increased to
$15.52/boe from $12.02/boe in Q4 2015 as a result of higher natural gas
sales prices partially offset by lower natural gas production.
— Natural gas sales decreased to $2,199 thousand in Q4 2016 from $3,433
thousand in Q4 2015 due to lower natural gas production partially offset
by an increase in the average natural gas price to $7.88/mscf in Q4 2016
from $6.99/mscf in Q4 2015. The decrease in the average daily natural
gas production to 3.0 mmscfpd in Q4 2016 from 5.3 mmscfpd in Q4 2015 is
due to management’s optimization strategy to partially shut-in its
natural gas production from September 2016 to November 2016 due to
higher anticipated pricing in the winter of 2016/2017.
— Corridor’s royalty expense for Q4 2016 decreased to $54 thousand from
$70 thousand for Q4 2015 due to lower natural gas sales in Q4 2016.
— Transportation expense for Q4 2016 decreased significantly to $239
thousand from $931 thousand for Q4 2015 due to management’s optimization
strategy to partially shut-in its natural gas production from September
2016 to November 2016 and the Company’s forward sale agreement in effect
from December 1, 2016 to March 31, 2017 for the sale of 4,755 mmbtupd of
natural gas production to the local Maritimes market as opposed to the
New England market. As a result, transportation expense per boe
decreased from $11.37/boe in Q4 2015 to $5.15/boe in Q4 2016.
— The decrease in net production expense to $616 thousand in Q4 2016 from
$785 thousand in Q4 2015 is due to the cost of workover operations of
$114 thousand during Q4 2015.
/T/
2016 Reserve Information
Corridor currently has natural gas reserves in the McCully Field near Sussex,
New Brunswick. GLJ assessed Corridor’s reserves in its report dated March 1,
2017 and effective as at December 31, 2016 (“2016 GLJ Reserves Report”) and its
updated report dated June 15, 2016 and effective December 31, 2015 (“GLJ 2015
Updated Reserves Report”) (collectively, the “GLJ Reports”) which were both
prepared in accordance with National Instrument 51-101 Standards of Disclosure
of Oil and Gas Activities (“NI 51-101”). The GLJ 2015 Updated Reserves Report
updated GLJ’s initial reserves report effective December 31, 2015 to assess the
impact on Corridor’s reserves of the New Brunswick Government’s announcement on
May 27, 2016 of its decision to continue the moratorium on hydraulic fracturing
for an indefinite period. The GLJ 2015 Updated Reserves Report demonstrated
that the New Brunswick Government’s decision resulted in a material reduction
in Corridor’s undeveloped reserves, future development capital and associated
net present value of future revenue as Corridor’s undeveloped wells no longer
qualified as reserves given that such wells require hydraulic fracture
stimulations. See Corridor’s material change report dated June 16, 2016, a copy
of which is filed on SEDAR at www.sedar.com.
The following table presents a summary from the GLJ Reports of Corridor’s total
gross natural gas and shale gas reserves, before the deduction of royalties,
using forecast prices and costs.
/T/
—————————————————————————-
2016 Gross Reserves 2015 Gross Reserves
Reserves Category bscf bscf
—————————————————————————-
Total proved 15.9 18.8
Total probable 4.1 4.1
—————————————————————————-
Total proved plus probable 20.0 22.9
—————————————————————————-
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The decrease in Corridor’s proved plus probable natural gas reserves from
December 31, 2015 to December 31, 2016 is primarily attributable to Corridor’s
production in 2016.
GLJ assessed the net present value of Corridor’s natural gas, oil and natural
gas liquids reserves in the GLJ Reports, based on GLJ’s forecast prices as at
January 1, 2016 and 2015, as applicable, as follows:
Net Present Value ($ in million) – undiscounted
/T/
—————————————————————————-
2016 2015
—————————————————————————-
Reserves Before Income After Income Before Income After Income
Category Tax(1) Tax(1) Tax(1) Tax(1)
—————————————————————————-
Proved 71.0 71.0 52.9 52.9
Proved plus
probable 93.9 93.9 70.5 70.5
—————————————————————————-
(1) The estimated value of future net revenue does not represent the fair
market value of Corridor’s reserves.
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Net Present Value ($ in million) – discounted at 10%
/T/
—————————————————————————-
2016 2015
—————————————————————————-
Reserves Before Income After Income Before Income After Income
Category Tax(1) Tax(1) Tax(1) Tax(1)
—————————————————————————-
Proved 45.8 45.8 39.3 39.3
Proved plus
probable 54.1 54.1 46.6 46.6
—————————————————————————-
(1) The estimated value of future net revenue does not represent the fair
market value of Corridor’s reserves.
/T/
The increase in the net present value of Corridor’s proved plus probable
natural gas reserves is primarily attributable to the increase in the estimate
of future natural gas revenues due to lower future transportation costs
expected as a result of an anticipated increase in the Company’s sales to the
local Maritimes market as opposed to the New England market.
A summary of the 2016 GLJ Reserves Report will be available on Corridor’s
website at www.corridor.ca on or about March 30, 2017 and in Corridor’s Annual
Information Form for the year ended December 31, 2016, which is filed on SEDAR
at www.sedar.com.
Anticosti Joint Venture
Corridor has a 21.67% interest in Anticosti Hydrocarbons L.P., which has
undeveloped lands on Anticosti Island, Quebec. The Anticosti Joint Venture is a
limited partnership 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. formed to appraise and potentially develop
hydrocarbon resources on Anticosti Island.
Beginning in December 2015, the Premier of Quebec stated on numerous occasions
that he is not in favor of the development of hydrocarbons on Anticosti Island
and that he is willing to face the financial consequences of pulling out of the
Anticosti Joint Venture and cancelling the agreements governing the Anticosti
Joint Venture. Subsequently, in March 2016, the Premier issued a statement
confirming that the Quebec Government would respect the Anticosti Joint Venture
agreements as long as the project met environmental standards.
In January 2017, the Quebec Government announced its decision to support the
designation of Anticosti Island as a UNESCO World Heritage site. If designated
as a UNESCO World Heritage site, the Anticosti Joint Venture would not be
permitted to engage in development or production of oil and gas on the Island.
While the Quebec Government confirmed its intention to respect the Anticosti
Joint Venture agreements, there is uncertainty that Anticosti Hydrocarbons’
drilling program will proceed in 2017. Corridor is reviewing its options to
ensure the value of its investment in Anticosti Hydrocarbons is protected.
Old Harry
On January 15, 2017, the Canada – Newfoundland and Labrador Offshore Petroleum
Board issued exploration license EL-1153 to Corridor in exchange for the
surrender of exploration license EL-1105 covering the Newfoundland and Labrador
sector of the Old Harry Prospect in the Gulf of St. Lawrence. The new
exploration license expires on January 14, 2020, subject to extension by
Corridor for an additional one year period (January 14, 2021) with the payment
of a $1 million deposit.
Corridor intends to purchase a user license for a controlled source
electro-magnetic (“CSEM”) data program to investigate the resistivity of
geological prospects over the Newfoundland and Labrador sector of the Old Harry
prospect, similar to resistivity logging in well bores of potential hydrocarbon
zones. Highly resistive layers in a geological structure measured with CSEM
technology could indicate hydrocarbon bearing reservoirs and, therefore, would
serve to reduce exploration risk and increase the likelihood of finding
commercial quantities of hydrocarbons. The undertaking of the CSEM program,
currently planned by an independent service provider for a seven day period in
the fall of 2017, is subject to the receipt of the necessary regulatory
approvals and vessel availability.
Guidance
Corridor has revised its guidance for the period from April 1, 2016 to March
31, 2017 from guidance previously disclosed on October 7, 2016 to reflect
actual results to December 31, 2016 and expected natural gas prices from
January 1, 2017 to March 31, 2017, as follows:
Revised Guidance from April 1, 2016 to March 31, 2017
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—————————————————————————
AGT average natural gas price $US 3.40/mmbtu
USD/CAD exchange rate $ 1.31 USD/CAD
Average natural gas price realized $ 5.70/mscf
Average daily natural gas production 5.5 mmscfpd
Field operating netback $ 7.2 million
Cash flow from operations (1) $ 4.4 million
Field operating netback per mscf $ 3.55/mscf
Cash flow from operations (1) per mscf $ 2.20/mscf
Capital expenditures (for the calendar year 2016) $ 0.4 million
Working capital estimate (as at March 31, 2017) $ 33.2 million
—————————————————————————
—————————————————————————
(1) Cash flow from operations is a non-IFRS measure. Cash flow from
operations represents net earnings adjusted for non-cash items including
depletion, depreciation and amortization, deferred income taxes, share-based
compensation and other non-cash expenses.
/T/
Notwithstanding a significant decrease in natural gas prices at AGT from those
previously forecasted for the first quarter of 2017, Corridor’s cash flow from
operations for the period from April 1, 2016 to March 31, 2017 is only expected
to decrease by $0.2 million to $4.4 million. This is due to the financial
hedges Corridor put in place and lower general and administrative expenses.
Corridor is currently evaluating alternatives for its optimization strategy for
the period from April 1, 2017 to March 31, 2018 and anticipates providing
guidance for that period at its annual shareholders’ meeting, currently
scheduled for May 11, 2017.
“Corridor is well positioned for 2017,” said Steve Moran, President and Chief
Executive Officer. “Our balance sheet is very strong, with a forecast $33.2
million of positive working capital at the end of Q1 2017. We are very pleased
with the results of our optimization strategy over the past two years, taking
advantage of the winter pricing premium of our natural gas market, while
preserving reserves for production in future years. We expect this winter
pricing premium to continue for the foreseeable future. Corridor has been
evaluating new opportunities to deploy our working capital, but with the
prolonged downturn in commodity prices, we have been patient in our approach.
We will continue to be selective in any opportunities we may decide to pursue.”
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 characteristics of Corridor’s and the Anticosti
Joint Venture’s properties; business plans and strategies (including plans to
shut-in production to take advantage of expected price differentials),
exploration and development plans, including timing of such plans (including
the CSEM and Anticosti Hydrocarbons L.P.’s plans); expectation of the price of
natural gas; expectations regarding Corridor’s financial resilience and plans
to maintain a strong balance sheet and the estimates of reserves and the net
present values of reserves; the financial position of the Company; government
plans, including in particular the Quebec Government’s plans in respect of the
Anticosti Joint Venture and Anticosti Island; and expectations regarding
natural gas prices, the U.S. Canada exchange rate, natural gas production,
operating netbacks, cash flow from operations, capital expenditures and working
capital estimates;
Statements relating to “reserves” are 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 can
profitably be produced in the future.
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 anticipated financial performance, business prospects, strategies,
regulatory developments, future natural gas commodity prices, future natural
gas production levels, the ability to obtain equipment in a timely manner to
carry out development activities, the ability to market natural gas
successfully to current and new customers, the impact of increasing
competition, the ability to obtain financing on acceptable terms, and the
ability to add production and reserves through development and exploration
activities. 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.
Oil and Gas Advisory
Boe Conversion
All calculations converting natural gas to crude oil equivalent have been made
using a ratio of six mscf of natural gas to one barrel of crude oil equivalent.
Boes may be misleading, particularly if used in isolation. A boe conversion
ratio of six mscf of natural gas to one barrel of crude 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.
– END RELEASE – 30/03/2017
For further information:
Steve Moran
President
Corridor Resources Inc.
(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: 20170330CC0131
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