BNK Petroleum Inc. Announces 4th Quarter and Annual 2013 Results

Camarillo, California (ots/PRNewswire) -

All amounts are in U.S. Dollars unless otherwise indicated:

Fourth Quarter Year Ended
2013 2012 % 2013 2012 %
Earnings
(Loss):
$ Thousands $(11,016) $(4,538) - $(19,710) $(14,948) -
$ per common
share $(0.08) $(0.03) - $(0.14) $(0.10) -
assuming
dilution
Capital
Expenditures $36,502 $4,945 638% $81,772 $40,537 102%
Average
Production
(Boepd) 877 1,681 (48%) 776 1,581 (51%)
Gross
Revenue 5,678 5,184 10% 13,995 20,028 (30%)
Average
Product
Price per
Barrel $70.39 $33.52 110% $49.39 $34.61 43%
Average
Netback per
Barrel $50.65 $17.83 184% $30.81 $17.75 74%
12/31/2013 12/31/2012
Cash, Cash
Equivalents
and
Marketable
Securities $42,215 $2,836
Working
Capital $18,854 $472

BNK's President and Chief Executive Officer, Wolf Regener
commented:

"I feel we have made excellent progress this last year on both our
U.S. and European projects. In our 2013 Tishomingo Field, Caney
formation drilling program, our efforts were focused on reducing
drilling time and cost, testing the optimal lateral placement within
the formation and optimizing the fracture stimulations resulting in
increasing the oil rate of each consecutive well. These goals were
achieved. The last two wells that we drilled and completed in 2013,
the Barnes 7-2H and the Wiggins 12-8H, have been our best performing
wells to date, demonstrating lower decline rates along with higher
percentages of oil in the production mix. The Barnes 7-2H well, which
still has 15% of the lateral left to fracture stimulate, had a 60 day
initial production rate of 360 barrels of oil per day (bopd) (469
barrels of oil equivalent per day (boepd)) and the Wiggins 12-8H
well, where only approximately half the length of the lateral was
effectively stimulated was 273 bopd (402 boepd). These two wells were
the first to be drilled in the lower Caney interval rather than the
Transition zone which was targeted in the first three wells. The
Company's fourth quarter average production was 877 boepd and our
December average production was approximately 1,050 boepd.

"The 2013 year end reserves report confirmed the Company's belief
in the potential for the Caney as the Company's proved and probable
("2P") gross reserves were estimated at approximately 15.5 million
boe, while the proved, probable and possible ("3P") gross reserves
were estimated at approximately 40.9 million boe. The net present
value of Future Net Revenue before tax, discounted at 10% was $286
million for the 2P reserves and $847 million for the 3P reserves.

"We look forward to starting our 2014 drilling program in the
second quarter after we obtain the final data from the Barnes 7-2
whole core analysis. Fracture stimulation operations are expected to
begin at the end of this month on the first of the two lateral Caney
wellbores that were not yet fully fracture stimulated (the remaining
15% of the Barnes 7-2H well and the Leila 31-2H well). In addition,
work on the locations and surface casing installation for the next
two Caney wells has already commenced and is expected to be finalized
in the coming weeks.

"In less than 8 months after selling substantially all of our
producing assets we were able to replace all of our revenue as our
fourth quarter 2013 revenues exceeded 2012 fourth quarter revenues by
over $400,000. Our cash flow from operations for the fourth quarter
2013 was $2.3 million, which is $1.5 million more than our 2012
fourth quarter operating cash flow. In addition, our Caney netbacks
for the fourth quarter 2013 averaged $50.65 per barrel, a 184%
increase over the netbacks from the Woodford production in the fourth
quarter of last year, which averaged $17.83 per barrel.

"In Poland, the Company successfully drilled, cased and cemented
the Gapowo B-1 well in its Bytow concession. We are encouraged by the
high gas shows encountered in the 5,900 feet of lateral and we look
forward to fracture stimulating the first thirty percent of the
available length. After this portion of the well has been tested we
will design the stimulation for the rest of the lateral,
incorporating what we learn from the first stimulation.

"The fracture stimulation design for the first portion of the
Gapowo B-1 well has been finalized, subcontractors have been selected
and location work is underway. We expect to commence fracture
stimulation of this well as soon as the location work is complete.

"In 2013, Saponis Investments Sp. z o.o ("Saponis") decided to
relinquish the Slawno and Starogard concessions, while retaining the
Slupsk concession. In December 2013, the Company increased its
ownership in Saponis to 57.04%, up from 26.7%. This triggered an
impairment test of the Company's Saponis interest under IFRS rules
and the resulting impairment plus the writedown of the two
concessions contributed to the Company recording a $7.5 million loss
from equity investments. However, the Company believes its interest
in Saponis is more valuable now than prior to these events due to its
increased interest in the more prospective Slupsk concession.

"The Company incurred an $11.0 million loss in the fourth quarter
of 2013, which includes the nonrecurring $7.5 million Saponis equity
investment loss and a $1.7 million write-off of the Darlowo lease in
Poland, versus a loss of $4.5 million in the fourth quarter of 2012.

"For the 2013 year the Company incurred a loss of $19.7 million
versus a loss of $14.9 million in 2012. Oil and gas revenues declined
$4.9 million, or 30%, due to a decrease in average production per day
due to the sale by the Company in April 2013 of all of its rights in
the Woodford and other formations in the Tishomingo Field (the
"Woodford Sale"), which was offset by production from our
subsequently drilled Caney wells and an increase in average pricing
per barrel.

"The Company recorded a gain of $9.5 million on the Woodford Sale,
and used a portion of the proceeds to pay down its debt from $41
million to $100,000. Offsetting this gain was $3.5 million related to
the amortization of deferred financing costs, a pre-payment penalty
of $2.5 million and a $2.5 million payment to settle all of our
financial commodity contracts."

FOURTH QUARTER HIGHLIGHTS:

- Drilled and fracture stimulated the Barnes 7-2H and Wiggins 12-8H wells in
the Caney formation in the Tishomingo Field
- Received required EIA and concession modification to drill Gapowo B-1 well
lateral in Poland
- In January 2014, completed the drilling and ran casing on the Gapowo B-1 well,
which is expected to be fracture stimulated in the second quarter of 2014
- Oil and gas revenues were $4.6 million, which exceeded the prior year quarter
for the first time since the Woodford Sale
- Cash flow from operating activities was $2.3 million compared to prior year
operating cash flows of $0.8 million
- Netbacks were $50.65 per barrel compared to $17.83 in the prior year fourth
quarter
- Production continued increasing, post Woodford Sale, and averaged 877 BOEPD in
the quarter
- G&A decreased by $1.0 million due to cost cutting efforts including reductions
in staff and lower costs in Europe
- Loss of $11.0 million in the fourth quarter of 2013 versus loss of $4.5
million in the third quarter of 2012 due to a loss from investments in joint ventures
of $7.4 million in 2013
- At quarter end, cash and marketable securities totaled $42.2 million and
working capital was $18.9 million

Fourth Quarter 2013 to Fourth Quarter 2012

Oil and gas revenues net of royalties totaled $4,613,000 in the
quarter versus $4,212,000 in the fourth quarter of 2012. Oil revenues
were $4,716,000 in the quarter versus $1,822,000 in the fourth
quarter of 2012, an increase of 159% as production increased 118% to
an average of 533 barrels per day due to the production mix from the
Caney wells while average oil prices increased 19% or $15.20 a
barrel. Natural gas revenues declined $1,008,000 or 79% as natural
gas production decreased to 690 mcfd due to the Woodford Sale and the
production mix of the Caney wells while average natural gas prices
per mcf increased 3%. NGL revenue declined $1,391,000 or 67% to
$690,000 as average production decreased 73% to 197 boepd as a result
of the Woodford Sale and the production mix from the Caney wells
while average NGL prices increased 22% to $38.03 a barrel.

Other income decreased $735,000 to $163,000 as fourth quarter 2012
results included gains from eliminating asset retirement obligations
for wells no longer owned by the Company.

Exploration and evaluation expenses increased $859,000 between
quarters due to the 2013 write-off of the Darlowo well in Poland.

Production and operating expenses declined $925,000 between
quarters due to the Woodford Sale.

Depletion and depreciation expense decreased $189,000 between
quarters due to decreased production and depletion base and lower
production as a result of the Woodford Sale.

General and administrative expenses decreased $954,000 between
quarters primarily due to lower payroll and related costs and lower
professional fees incurred in Europe relating to legal, accounting,
and management fees which were partially offset by higher director
fees incurred in 2013.

Stock based compensation increased $524,000 between quarters due
to a grant of stock options in the fourth quarter of 2013.

Finance income decreased $344,000 due to realized gains on
financial commodity contracts in 2012. Finance expense decreased
$774,000 primarily due to interest on loans and borrowings of
$384,000 in 2012 and unrealized losses on financial commodity
contracts in 2012.

Capital expenditures of $36,502,000 were incurred in the fourth
quarter of 2013, almost all of which was spent in Oklahoma.

YEAR ENDED 2013 HIGHLIGHTS

- Drilled and fracture stimulated the first five wells in the Caney
formation in the Tishomingo field
- Closed the Woodford Sale in April 2013 for $146.4 million
- Paid down the Company's credit facility from $41 million to $100,000 in
connection with the Woodford Sale
- Settled all the financial derivative contracts in April 2013 in connection
with the Woodford Sale and incurred a realized loss of $2.5 million
- Capital expenditures increased $40.7 million or 99% to $81.8 million primarily
due to the 2013 drilling program in Oklahoma which totaled $78.1 million for the year
ended 2013. The 2012 capital expenditures amount included $28 million of capital
expenditures for exploration and evaluation assets, mainly in Poland
- G&A expenses decreased by $2.9 million primarily due to staff reductions and
lower costs in Europe
- Average production decreased 51% between comparative years due to the Woodford
Sale, which was partially offset by production from the new Caney wells
- A net loss of $19.7 million was incurred in the year ended 2013 versus a loss
of $14.9 million in in 2012 partially due to a loss from investments in joint ventures
of $7.5 million in 2013 and the $1.7 million write-off of the Polish Darlowo
concession

Year Ended 2013 to Year Ended 2012

Oil and natural gas revenues net of royalties declined $4,902,000
or 30% to $11,371,000. Oil revenues before royalties increased
$624,000 to $9,149,000 due to a 2% increase in production due to the
production mix from the Caney wells and a 6% increase in prices
between years. Natural gas revenues before royalties declined
$2,086,000 or 54% due to a 62% decline in average production due to
the Woodford Sale and production mix from the Caney wells, partially
offset by a 23% increase in natural gas prices per mcf. NGL revenue
before royalties declined $4,574,000 or 60% to $3,054,000 due to a
60% decline in average production per day due to the Woodford Sale
and the production mix from the Caney wells.

Other income decreased due to 2012 gains from eliminating asset
retirement obligations for wells no longer owned by the Company.

Exploration and evaluation expenses increased $606,000 due to the
write-off of the Darlowo concession in Poland.

Production and operating expenses decreased 56% to $2,641,000 as
average production decreased 51% due to the Woodford Sale.

Depletion and depreciation expense decreased $2,288,000 primarily
due to decreased production and depletion base and lower production
as a result of the Woodford Sale.

General and administrative expenses decreased $2,935,000 primarily
due to lower payroll and related costs, lower professional fees
incurred in Europe relating to legal, accounting, management fees and
lower travel costs partially offset by higher director fees in 2013.

Finance Income decreased $1.5 million due to realized gains on
financial commodity contracts and unrealized gains on warrant
revaluations in 2012. Finance expense increased $7.6 million
primarily due to a $7.5 million charge related to interest on loans
and borrowings which included $3.5 million for the amortization of
deferred financings costs and $2.5 million of pre-payment penalties
related to the loan paydown along with a realized loss on financial
commodity contracts of $2.5 million as these contracts were all
settled in April 2013.

At December 31, 2013, cash and marketable securities increased by
$39,379,000 from December 31, 2012, primarily due to the Woodford
Sale offset by the 2013 capital expenditures.

BNK PETROLEUM INC.
CONDENSED CONSOLIDATED STATEMENTS OF FINANCIAL POSITION
(Unaudited, Expressed in Thousands of United States Dollars)
December
December 31, 31,
2013 2012
Current assets
Cash and cash
equivalents $ 17,159 $ 2,836
Investments in
marketable
securities 25,056 -
Trade and other
receivables 7,268 11,363
Deposits and
prepaid expenses 1,243 2,334
Fair value of
commodity
contracts - 779
50,726 17,312
Non-current assets
Long-term
receivables 433 1,297
Investments in
joint ventures 2,787 10,114
Property, plant
and equipment 94,663 156,549
Exploration and
evaluation assets 36,194 33,590
134,077 201,550
Total assets $ 184,803 $ 218,862
Current liabilities
Trade and other
payables $ 31,872 $ 16,840
Loans and
borrowings - 31,797
31,872 48,637
Non-current liabilities
Loans and
borrowings 100 -
Fair value of
commodity
contracts - 75
Asset retirement
obligations 1,192 1,312
Warrants - 3
1,292 1,390
Equity
Share capital 247,782 247,326
Contributed
surplus 18,721 16,663
Deficit (114,864) (95,154)
Total equity 151,639 168,835
Total equity and liabilities $ 184,803 $ 218,862

BNK PETROLEUM, INC.
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS AND
COMPREHENSIVE LOSS
(Unaudited, expressed in Thousands of United States dollars,
except per share amounts)
Three months ended Twelve months ended
December 31 December 31
2013 2012 2013 2012
Revenue:
Oil and natural gas
revenue, net $ 4,613 $ 4,212 $ 11,371 $ 16,273
Gathering income - 356 331 1,420
Gain on sale of
assets (119) - 9,499 -
Management fees and
other income 163 898 1,124 1,633
4,657 5,466 22,325 19,236
Expenses:
Exploration and
evaluation 1,937 1,078 1,994 1,388
Production and
operating 528 1,453 2,641 6,002
Depletion and
depreciation 1,729 1,918 4,786 7,074
General and
administrative 3,414 4,368 13,344 16,279
Share based
compensation 716 192 1,305 877
Loss from
investments in
joint ventures 7,439 (101) 7,533 172
Restructuring
expenses - 756 595 1,771
15,763 9,664 32,198 33,563
Finance income 97 441 166 1,686
Finance expense (7) (781) (10,003) (2,397)
Net loss and
comprehensive loss $ (11,016) $ (4,538) $ (19,710) $ (14,948)
Net loss per share
Basic and
Diluted $ (0.08) $ (0.03) $ (0.14) $ (0.10)

BNK PETROLEUM, INC.
FOURTH QUARTER 2013
(Unaudited, expressed in Thousands of United States dollars,
except as noted)
4th Quarter
2013 2012 2013 2012
Oil revenue
before
royalties $ 4,716 1,822 9,149 8,525
Gas revenue
before
royalties 273 1,281 1,787 3,873
NGL revenue
before
royalties 690 2,081 3,054 7,628
Oil and Gas
revenue 5,679 5,184 13,990 20,026
Cash flow used
by operating
activities 2,286 784 (6,656) (10,153)
Additions to
property,
plant &
equipment (34,504) (3,982) (78,386) (12,915)
Additions to
Exploration
and Evaluation
Assets (1,998) (963) (3,386) (27,622)

Statistics:
4th Quarter
2013 2012 2013 2012
Average
natural gas
production
(mcf/d) 879 4,240 1,504 3,981
Average NGL
production
(Boepd) 197 729 264 660
Average Oil
production
(Bopd) 533 245 261 257
Average
production
(Boepd) 877 1,681 776 1,581
Average
natural gas
price ($/mcf) $ 3.38 $3.28 $3.26 $2.66
Average NGL
price ($/bbl) $ 38.03 $31.02 $31.69 $31.58
Average oil
price ($/bbl) $ 96.13 $80.93 $95.93 $90.59
Average price
per barrel $ 70.39 $33.52 $49.39 $34.61
Royalties per
barrel 13.20 6.29 9.26 6.49
Operating
expenses per
barrel 6.54 9.40 9.32 10.37
Netback per
barrel $ 50.65 $17.83 $30.81 $17.75

The information outlined above is extracted from and should be
read in conjunction with the Company's audited financial statements
for the year ended December 31, 2013 and the related management's
discussion and analysis thereof, copies of which are available under
the Company's profile at http://www.sedar.com.

NON-GAAP MEASURES

Netback per barrel, net operating income and funds from operations
(collectively, the "Company's Non-GAAP Measures") are not measures
recognized under Canadian generally accepted accounting principles
("GAAP") and do not have any standardized meanings prescribed by
GAAP. Management of the Company believes that such measures are
relevant for evaluating returns on each of the Company's projects as
well as the performance of the enterprise as a whole. The Company's
Non-GAAP Measures may differ from similar computations as reported by
other similar organizations and, accordingly, may not be comparable
to similar non-GAAP measures as reported by such organizations. The
Company's Non-GAAP Measures should not be construed as alternatives
to net income, cash flows related to operating activities, or other
financial measures determined in accordance with GAAP, as an
indicator of the Company's performance.

Netback per barrel and its components are calculated by dividing
revenue less royalties and operating expenses by the Company's sales
volume during the period. Netback per barrel is a non-IFRS measure
but it is commonly used by oil and gas companies to illustrate the
unit contribution of each barrel produced. This is a useful measure
for investors to compare the performance of one entity with another.
However, non-IFRS measures do not have any standardized meaning
prescribed by IFRS and therefore may not be comparable to similar
measures used by other companies.

Net operating income is similarly a non-GAAP measure that
represents revenue net of royalties and operating expenses. The
Company believes that net operating income is a useful supplemental
measure to analyze operating performance and provides an indication
of the results generated by the Company's principal business
activities prior to the consideration of other income and expenses.

Funds from operations is a non-GAAP measure that represents cash
provided by (used in) operating activities, as per the consolidated
statements of cash flows, before changes in non-cash working capital.
The Company considers this a key measure as it demonstrates its
ability to generate the funds necessary for future growth after
taking into account the short-term fluctuations in the collection of
accounts receivable and the payment for accounts payable.

Cautionary Statements

The Company's natural gas production is reported in thousands of cubic
feet ("Mcfs"). The Company also uses references to barrels ("Bbls")
and barrels of oil equivalent ("Boes") to reflect natural gas liquids
and oil production and sales. Boes may be misleading, particularly if
used in isolation. A Boe conversion ratio 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 different from the energy
equivalency of 6:1, utilizing a conversion on a 6:1 basis may be
(a) misleading as an indication of value.
Discounted and undiscounted net present value of future net revenues
(b) attributable to reserves do not represent fair market value.
Possible reserves are 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
(c) proved plus probable plus possible reserves.
This news release contains short-term production rates. Readers are
cautioned that such production rates are not necessarily indicative of
(d) long-term performance or of ultimate recovery.

Readers are referred to the full description of the results of the
Company's December 31, 2013 independent reserves evaluation and other
oil and gas information contained in its Amended and Restated Form
51-101F1 Statement of Reserves Data and Other Oil and Gas Information
for the year ended December 31, 2013, which the Company filed on
SEDAR on March 10, 2014.

Caution Regarding Forward-Looking Information

This release contains forward-looking information including
information regarding estimates of reserves and future net revenue,
the proposed timing and expected results of exploratory and
development work including production from the Lower Caney and upper
Sycamore formations on the Company's Oklahoma acreage, the effect of
design and performance improvements on future productivity, the
anticipated timing of commencement and completion of drilling and
fracture-stimulations in connection with the Company's Caney drilling
program, the advancement of the Company's European projects,
including permit and concession applications and approvals, drilling
plans and fracture stimulation operations underway on the Company's
Gapowo B-1 shale gas well in Poland, planned capital expenditure
programs and cost estimates, planned use and sufficiency of cash and
marketable securities on hand and the Company's strategy and
objectives. The use of any of the words "target", "plans",
"anticipate", "continue", "estimate", "expect", "may", "will",
"project", "should", "believe" and similar expressions are intended
to identify forward-looking statements.

Such forward-looking information is based on management's
expectations and assumptions, including that the Company's geologic
models will be validated, that indications of early results are
reasonably accurate predictors of the prospectiveness of the shale
intervals, that previous exploration results are indicative of future
results and success, that expected production from future wells can
be achieved as modeled, declines will match the modeling, future well
production rates will be improved over existing wells, that rates of
return as modeled can be achieved, that recoveries are consistent
with management's expectations, that additional wells are actually
drilled and completed, that design and performance improvements will
reduce development time and expense and improve productivity, that
discoveries will prove to be economic, that anticipated results and
estimated costs will be consistent with managements' expectations,
that all required permits and approvals and the necessary labor and
equipment will be obtained, provided or available, as applicable, on
terms that are acceptable to the Company, when required, that no
unforeseen delays, unexpected geological or other effects, equipment
failures, permitting delays or labor or contract disputes are
encountered, that the development plans of the Company and its
co-venturers will not change, that the demand for oil and gas will be
sustained, that the Company will continue to be able to access
sufficient capital through financings, credit facilities, farm-ins or
other participation arrangements to maintain its projects, that the
Company will not be adversely affected by changing government
policies and regulations, social instability or other political,
economic or diplomatic developments in the countries in which it
operates and that global economic conditions will not deteriorate in
a manner that has an adverse impact on the Company's business and its
ability to advance its business strategy.

Forward looking information involves significant known and unknown
risks and uncertainties, which could cause actual results to differ
materially from those anticipated. These risks include, but are not
limited to: any of the assumptions on which such forward looking
information is based vary or prove to be invalid, including that
anticipated results and estimated costs will not be consistent with
managements' expectations, the risks associated with the oil and gas
industry (e.g. operational risks in development, exploration and
production; delays or changes in plans with respect to exploration
and development projects or capital expenditures; the uncertainty of
reserve and resource estimates and projections relating to
production, costs and expenses, and health, safety and environmental
risks), the risk of commodity price and foreign exchange rate
fluctuations, risks and uncertainties associated with securing the
necessary regulatory approvals and financing to proceed with
continued development of the Tishomingo Field and other shale basins
in the United States and Europe, the Company or its subsidiaries is
not able for any reason to obtain and provide the information
necessary to secure required approvals or that required regulatory
approvals are otherwise not available when required, that unexpected
geological results are encountered, that completion techniques
require further optimization, that production rates do not match the
Company's assumptions, that very low or no production rates are
achieved, that the Company is unable to access required capital, that
occurrences such as those that are assumed will not occur, do in fact
occur, and those conditions that are assumed will continue or
improve, do not continue or improve and the other risks identified in
the Company's most recent Annual Information Form under the "Risk
Factors" section and the Company's other public disclosure, available
under the Company's profile on SEDAR at http://www.sedar.com.

With respect to estimated reserves and future net revenue, the
evaluation of the Company's reserves is based on a limited number of
wells with limited production history and includes a number of
assumptions relating to factors such as availability of capital to
fund required infrastructure, commodity prices, production
performance of the wells drilled, successful drilling of infill
wells, the assumed effects of regulation by government agencies and
future operating costs. All of these estimates will vary from actual
results. Estimates of the recoverable oil and natural gas reserves
attributable to any particular group of properties, classifications
of such reserves based on risk of recovery and estimates of future
net revenues expected therefrom, may vary. The Company's actual
production, revenues, taxes, development and operating expenditures
with respect to its reserves will vary from such estimates, and such
variances could be material. In addition to the foregoing, other
significant factors or uncertainties that may affect either the
Company's reserves or the future net revenue associated with such
reserves include material changes to existing taxation or royalty
rates and/or regulations, and changes to environmental laws and
regulations.

Although the Company has attempted to take into account important
factors that could cause actual costs or results to differ
materially, there may be other factors that cause actual 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 statements. The forward-looking information
included in this release is expressly qualified in its entirety by
this cautionary statement. Accordingly, readers should not place
undue reliance on forward-looking information. The Company undertakes
no obligation to update these forward-looking statements, other than
as required by applicable law.

About BNK Petroleum Inc. BNK Petroleum Inc. is an international
oil and gas exploration and production company focused on finding and
exploiting large, predominately unconventional oil and gas resource
plays. Through various affiliates and subsidiaries, the Company owns
and operates shale gas properties and concessions in the United
States, Poland and Spain. Additionally the Company is utilizing its
technical and operational expertise to identify and acquire
additional unconventional projects. The Company's shares are traded
on the Toronto Stock Exchange under the stock symbol BKX.

For further information: Wolf E. Regener, President and Chief
Executive Officer, +1(805)484-3613, Email:
investorrelations@bnkpetroleum.com

Website: http://www.bnkpetroleum.com

ots Originaltext: BNK Petroleum Inc.
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