Bighorn Petroleum Ltd., Flying A Petroleum Ltd., Tenaka Drilling Consortium Ltd. and Wyn Developments Inc. announce 51-101 reserves estimates and sign a binding amalgamation agreement



    VANCOUVER, Sept. 19 /CNW/ - Bighorn Petroleum Ltd. (TSXV: BHP,
"Bighorn"), Flying A Petroleum Ltd. (TSXV: FAB, "Flying A"), Tenaka Drilling
Consortium Ltd. ("Tenaka") and Wyn Developments Inc. (TSXV: WL, FWB: YXE,
OTCBB: WYDPF, "Wyn"), (collectively the "Partners"), have received Reliance
Engineering Group Ltd.'s ("Reliance") independent national instrument 51-101
compliant property reserve evaluation for all drilled sections of the Prophet
River, Bougie Trutch, and Trutch East land holdings. The Company also
announces the Partners have signed a binding amalgamation agreement, the
particulars of which are also outlined in this news release.

    
                      51-101 RESERVES ESTIMATES
    

    Foreword

    The following tables summarize the data contained in the Reliance Report
and as a result may contain slightly different numbers than the Reliance
Report due to rounding. All future cash flows are stated prior to provision
for income taxes and indirect costs and after deduction of royalties,
estimated future capital expenditures and well abandonment costs. It should
not be assumed that the present worth of estimated future cash flows shown
below is representative of the fair market value of the reserves. There is no
assurance that such price and cost assumptions will be attained and variances
could be material. The Company's recovery and reserve estimates of natural gas
reserves provided herein are estimates only and there is no guarantee that the
estimated reserves will be recovered. Actual reserves may be greater than or
less than the estimates provided herein. Political and economic uncertainties
domestically and internationally may result in forecast prices different from
those used in the report.
    This Reliance report does not provide estimates or reserves for the
approximately 50 square miles across all properties that have not been drilled
and are considered highly prospective. The Reliance 51-101 F1 reserve
statement only estimates proven and probable reserves on all drilled lands
which comprise of 1 full Prophet River section (approx. 1 square mile), 4 half
spacing sections at Bougie Trutch (approx. 2 square miles) and 1 half section
at Trutch East (approx. 1/2 of 1 square mile). The 51-101 F1 statement does
not contain any possible reserves which have been allocated to any sections.
The complete 51-101 F1 Statement of Reserves Data, dated as of the Partners'
fiscal year ends and prior to any production, is available at www.sedar.com.

    Key Definitions

    Proved Reserves

    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. There is a 90%
probability that at least the estimated proved reserves will be recovered.

    Probable 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. There is a 50% probability that at
least the sum of the estimated proved reserves plus probable reserves will be
recovered.

    Possible Reserves

    Possible reserves are 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. There is a 10% probability that at least the sum of
the estimated proved reserves plus probable reserves plus possible reserves
will be recovered.

    Further definition and explanation of the terms and methods utilized in
this calculation can be found in section 5 of the Canadian Oil and Gas
Evaluation Handbook.

    Pricing Assumptions

    
        Forecast Prices and Costs

    Reliance used the following pricing, exchange rate and inflation rate
assumptions as of January 31, 2007 in estimating the Partners' reserves data
using forecast prices and costs.


                   Crude Oil          Natural   NGLs
                                        Gas
        ---------------------------------------------
                     Edmon-     Bow
                   ton Par    River
                     Price   Medium   British
              WTI       40     25.3  Columbia                  Infla-
          Cushing  degrees  degrees             NGL  Exchange   tion
         Oklahoma      API      API      Spot   Mix      Rate   Rate
        -------------------------------------------------------------
             ($US/      ($/      ($/       ($/   ($/     ($US/    (%/
              bbl)     bbl)     bbl)    MMBtu)  bbl)     $Cdn)  Year)

    2007    62.00    70.25    49.00    7.05    59.10    0.87    1.50
    2008    60.00    68.00    49.00    7.30    55.85    0.87    1.50
    2009    58.00    65.75    48.75    7.60    54.05    0.87    1.50
    2010    57.00    64.50    48.25    7.65    53.00    0.87    1.50
    2011    57.00    64.50    49.00    7.70    53.00    0.87    1.50
    2012    57.50    65.00    49.50    8.00    53.35    0.87    1.50
    2013    58.50    66.25    50.25    8.12    54.15    0.87    1.50
    2014    59.75    67.75    51.50    8.24    54.96    0.87    1.50
    2015    61.00    69.00    52.50    8.37    55.79    0.87    1.50
    2016    62.25    70.50    53.50    8.49    56.62    0.87    1.50
    2017+   63.50    71.75    54.50    8.62    57.47    0.87    1.50
    -----------------------------------------------------------------
    Escalation Rate of 1.5% thereafter


                       BIGHORN 51-101 RESERVE ESTIMATES

    Bighorn's Summary of Oil and Natural Gas Reserves - Forecast
    Prices and Costs

                      Gross Reserves              Net Reserves
             --------------------------------------------------------
                  Light                      Light
                    and           Natural      and           Natural
                 Medium  Natural      Gas   Medium  Natural      Gas
                    Oil      Gas  Liquids      Oil      Gas  Liquids
                  (Mbbl)   (MMcf)   (Mbbl)   (Mbbl)   (MMcf)   (Mbbl)
    -----------------------------------------------------------------

    Proved
      Developed
       Producing      -        -        -        -        -        -
      Developed
       Non-
       Producing      -      733        -        -      528      1.3
      Undeveloped     -        -        -        -        -        -
    -----------------------------------------------------------------
    Total Proved      -      733        -        -      528      1.3
    Probable          -     2133        -        -     1430      1.8
    -----------------------------------------------------------------
    Total Proved
     Plus Probable    -     2866        -        -     1958      3.1
    -----------------------------------------------------------------
    -----------------------------------------------------------------


    Bighorn's Net Present Value of Future Net Revenue - Forecast
    Prices and Costs

                           After Income Taxes, Discounted at (%/Year)
                          -------------------------------------------
                               0        5       10       15       20
    -----------------------------------------------------------------
                             (M$)     (M$)     (M$)     (M$)     (M$)
    Proved
      Developed
       Producing               -        -        -        -        -
      Developed
       Non-Producing       2,269    1,751    1,391    1,131      940
      Undeveloped              -        -        -        -        -
    -----------------------------------------------------------------
    Total Proved           2,269    1,751    1,391    1,131      940
    Probable               6,034    4,643    3,688    3,004    2,494
    -----------------------------------------------------------------
    Total Proved
     Plus Probable         8,303    6,394    5,079    4,135    3,434
    -----------------------------------------------------------------
    -----------------------------------------------------------------

    The Company's non-capital losses of previous years combined with
    the Corporate Tax Pools results in no income tax being paid, and
    therefore the before tax present values are the same as the after
    tax present values. Bighorn's report is dated as of January 31st,
    2007, not Bighorn's December 31st, 2007 year end as the Company
    had no revenue from production nor reserves as of that date. The
    January 31st, 2007 51-101 report is being used to value Bighorn's
    natural gas assets at the same date as the other amalgamation
    Partners.


                  FLYING A 51-101 RESERVE ESTIMATES

    Flying A's Summary of Oil and Natural Gas Reserves - Forecast
    Prices and Costs

                      Gross Reserves              Net Reserves
             --------------------------------------------------------
                  Light                      Light
                    and           Natural      and           Natural
                 Medium  Natural      Gas   Medium  Natural      Gas
                    Oil      Gas  Liquids      Oil      Gas  Liquids
                  (Mbbl)   (MMcf)   (Mbbl)   (Mbbl)   (MMcf)   (Mbbl)
    -----------------------------------------------------------------

    Proved
      Developed
       Producing      -        -        -        -        -        -
      Developed
       Non-
       Producing      -     1287     10.0        -      839      7.2
      Undeveloped     -        -        -        -        -        -
    -----------------------------------------------------------------
    Total Proved      -     1287     10.0        -      839      7.2
    Probable          -     2943     14.5        -     1891     10.5
    -----------------------------------------------------------------
    Total Proved
     Plus Probable    -     4230     24.5        -     2730     17.7
    -----------------------------------------------------------------
    -----------------------------------------------------------------


    Flying A's Net Present Value of Future Net Revenue - Forecast
    Prices and Costs

                          After Income Taxes, Discounted at (%/Year)
                         --------------------------------------------
                               0        5       10       15       20
    -----------------------------------------------------------------
                             (M$)     (M$)     (M$)     (M$)     (M$)
    Proved
      Developed
       Producing               -        -        -        -        -
      Developed
       Non-Producing       3,586    2,844    2,317    1,931    1,641
      Undeveloped              -        -        -        -        -
    -----------------------------------------------------------------
    Total Proved           3,586    2,844    2,317    1,931    1,641
    Probable               8,976    6,725    5,199    4,120    3,330
    -----------------------------------------------------------------
    Total Proved
     Plus Probable        12,562    9,569    7,516    6,051    4,971
    -----------------------------------------------------------------
    -----------------------------------------------------------------

    The Company's non-capital losses of previous years combined with
    the Corporate Tax Pools results in no income tax being paid, and
    therefore the before tax present values are the same as the after
    tax present values.


                   TENAKA 51-101 ROYALTY ESTIMATES

    Summary of Oil and Natural Royalties - Forecast Prices and Costs

                      Gross Reserves              Net Reserves
             --------------------------------------------------------
                  Light                      Light
                    and           Natural      and           Natural
                 Medium  Natural      Gas   Medium  Natural      Gas
                    Oil      Gas  Liquids      Oil      Gas  Liquids
                  (Mbbl)   (MMcf)   (Mbbl)   (Mbbl)   (MMcf)   (Mbbl)
    -----------------------------------------------------------------

    Proved
      Developed
       Producing      -        -        -        -        -        -
      Developed
       Non-
       Producing      -        -        -        -      126      1.3
      Undeveloped     -        -        -        -        -        -
    -----------------------------------------------------------------
    Total Proved      -        -        -        -      126      1.3
    Probable          -        -        -        -      253      1.8
    -----------------------------------------------------------------
    Total Proved
     Plus Probable    -        -        -        -      379      3.1
    -----------------------------------------------------------------
    -----------------------------------------------------------------


    Net Present Value of Future Net Revenue - Forecast Prices and
    Costs

                         Before Income Taxes, Discounted at (%/Year)
                        ---------------------------------------------
                               0        5       10       15       20
    -----------------------------------------------------------------
                             (M$)     (M$)     (M$)     (M$)     (M$)
    Proved
      Developed
       Producing               -        -        -        -        -
      Developed
       Non-Producing         892      706      578      486      418
       Undeveloped             -        -        -        -        -
    -----------------------------------------------------------------
    Total Proved             892      706      578      486      418
    Probable               1,756    1,336    1,055      858      714
    -----------------------------------------------------------------
    Total Proved
     Plus Probable         2,648    2,042    1,633    1,344    1,132
    -----------------------------------------------------------------
    -----------------------------------------------------------------


                     WYN 51-101 RESERVE ESTIMATES

    Wyn's Summary of Oil and Natural Gas Reserves - Forecast Prices
    and Costs

                      Gross Reserves              Net Reserves
             --------------------------------------------------------
                  Light                      Light
                    and           Natural      and           Natural
                 Medium  Natural      Gas   Medium  Natural      Gas
                    Oil      Gas  Liquids      Oil      Gas  Liquids
                  (Mbbl)   (MMcf)   (Mbbl)   (Mbbl)   (MMcf)   (Mbbl)
    -----------------------------------------------------------------

    Proved
      Developed
       Producing      -        -        -        -        -        -
      Developed
       Non-
       Producing      -     1208      8.5        -      784      6.1
      Undeveloped     -        -        -        -        -        -
    -----------------------------------------------------------------
    Total Proved      -     1208      8.5        -      784      6.1
    Probable          -     2827     12.4        -     1811      9.0
    -----------------------------------------------------------------
    Total Proved
     Plus Probable    -     4035     20.9        -     2595     15.1
    -----------------------------------------------------------------
    -----------------------------------------------------------------


    Wyn's Net Present Value of Future Net Revenue - Forecast Prices
    and Costs

                         After Income Taxes, Discounted at (%/Year)
                       ----------------------------------------------
                               0        5       10       15       20
    -----------------------------------------------------------------
                             (M$)     (M$)     (M$)     (M$)     (M$)
    Proved
      Developed
       Producing               -        -        -        -        -
      Developed
       Non-Producing       3,320    2,625    2,132    1,772    1,500
      Undeveloped              -        -        -        -        -
    -----------------------------------------------------------------
    Total Proved           3,320    2,625    2,132    1,772    1,500
    Probable               8,571    6,425    4,970    3,942    3,190
    -----------------------------------------------------------------
    Total Proved
     Plus Probable        11,891    9,050    7,102    5,714    4,690
    -----------------------------------------------------------------
    -----------------------------------------------------------------

    The Company's non-capital losses of previous years combined with
    the Corporate Tax Pools results in no income tax being paid, and
    therefore the before tax present values are the same as the after
    tax present values.


                     FUTURE DEVELOPMENT POTENTIAL
    

    The Partners have also analyzed all known data of the Prophet River,
Bougie Trutch and Trutch East Lands (including 2D and 3D seismic) to determine
their future development potential. The aforementioned reserves estimates only
pertain to proven and probable reserves on all drilled lands which comprise of
1 full Prophet River section (approx. 1 square mile), 4 half spacing sections
at Bougie Trutch (approx. 2 square miles) and 1 half section at Trutch East
(approx. 1/2 of 1 square mile). The 51-101 F1 statement does not contain any
possible reserves which have been allocated to any sections. The Partners have
identified approximately 54 additional prospective development locations
across all earned and optioned lands, broken down as follows:

    
    -   5 additional Mississippian/Halfway Formation dual production
        targets on the combined Prophet River lands.

    -   9 additional Halfway Formation targets on the combined
        Prophet River lands.

    -   27 additional Halfway Formation targets on the Bougie Trutch
        lands.

    -   13 additional Halfway Formation targets on the Trutch East
        lands based on earned and optioned lands.

    -   Multiple Slave Point Formation targets at Prophet River and
        Bougie Trutch for future consideration.
    

    The Company is on schedule to start drilling these additional development
locations this 2007/2008 winter season. More detail on these development plans
will be provided once finalized.

    
                  THE CANADA GAS CORP. AMALGAMATION

    The Partners continue to progress on the proposed business combination to
create a new junior Canadian natural gas development company, having signed a
binding Letter of Amalgamation on September 12, 2007. The name of the
amalgamated company shall be "Canada Gas Corp." and will be referred to as
such henceforth.

    Current Share Structures

                                               Warrant         Fully
                             Outstanding     & Options       Diluted

    Bighorn Petroleum Ltd.    27,693,079    11,812,217    39,505,296

    Flying A Petroleum Ltd.   76,324,570    26,721,284   103,045,854

    Tenaka Drilling
     Consortium Ltd.                 100           NIL           100

    Wyn Developments Inc.     79,965,609    21,611,729   101,577,338
    

    The aggregate assets and liabilities of the Partners', Prophet River,
Bougie Trutch and Trutch East assets will become the assets and liabilities of
Canada Gas Corp., save and except for Wyn Developments Inc.'s mineral assets
together with the accompanying respective liabilities. Wyn Developments will
enter into an agreement with an entity created by them (the "Newco") to
transfer the Excluded Assets and Liabilities to their Newco in a manner that
results in their respective securityholders becoming securityholders of the
Newco immediately prior to the effective date of the Amalgamation. Bighorn
Petroleum Ltd. and Flying A Petroleum Ltd. will also follow this methodology
upon the successful acquisition of a secondary asset prior to the
amalgamation. Currently, neither Bighorn Petroleum Ltd. or Flying A Petroleum
Ltd. have secondary assets which would constitute qualifying properties for
their respective spinout Newcos to obtain a listing on the TSX Venture
Exchange. There can be no assurance that they will obtain such assets and be
able to proceed and complete plans of arrangement in time for the Partners to
meet their planned time line for completion of the amalgamation. These spin
outs are all subject to TSX Venture Exchange approval.
    The Partners have agreed to the approximate share exchange ratios
predicated upon the independent reserve analysis and subsequent determination
of net asset value of oil and gas assets in aggregate. The Partners'
shareholders will receive approximate share exchange ratios equivalent to the
following:

    
    Canada Gas Corp. Share Exchange Ratios(1):


    Bighorn            1.563 Bighorn shares
     Petroleum Ltd.     for 1 CGC share equals            22,004,150


    Flying A           1.9387 Flying A shares
     Petroleum Ltd.     for 1 CGC share equals            39,368,100


    Tenaka Drilling    All Tenaka shares
     Consortium Ltd.    for CGC shares equals              4,298,886


    Wyn Developments   2.3294 Wyn shares
     Inc.               for 1 CGC share equals            34,328,870


    Total Canada Gas Corp. common shares
     to be issued on the Effective Date:                 100,000,000


    Number of Canada Gas Corp. Warrants to be held by each Partner's
    warrant holders after share exchange(2)(4):

              Bighorn Petroleum Ltd.                3,270,633

              Flying A Petroleum Ltd.              12,441,998

              Tenaka Drilling Consortium Ltd.             Nil

              Wyn Developments Inc.                 7,560,629


    Total Canada Gas Corp. Warrants
     outstanding on Effective Date:                       23,273,260


    Number of Canada Gas Corp. Options to be held by each Partner's
    option holders after share exchange(3)(4):

              Bighorn Petroleum Ltd.                1,760,332

              Flying A Petroleum Ltd.               3,149,448

              Tenaka Drilling Consortium Ltd.         343,909

              Wyn Developments Inc.                 2,746,311

    Total Canada Gas Corp. Options:                        8,000,000


    Number of new Canada Gas Corp. Options reserved for grant to
    officers, senior management, employees and consultants:
                                                           2,000,000

    Number of performance shares reserved for issuance to senior
    management:
                                                           2,000,000

    Total Number of Canada Gas Corp. Options, New Options and
    Performance Shares granted or available for grant or issue on the
    Effective Date of the amalgamation:
                                                          12,000,000

    Canada Gas Corp. Fully Diluted Share Structure as at the
    Effective Date(*):

                             135,273,260


    (*) The fully diluted issued capital as at the effective date of
    the amalgamation may vary from the number contained in this
    release as a result of share issuances that could occur that are
    not contemplated at this time or amendments which may occur to
    the terms of the amalgamation agreement.

    (1) No fractional shares will be issued pursuant to the
    Amalgamation. In the event that the conversions contemplated by
    the Amalgamation would result in a shareholder being entitled to
    a fractional share, the number of shares to be issued to each
    such shareholder will be rounded down to the next whole number of
    shares. The ratios are subject to change as a result of audit
    reviews dated July 31, 2007 and any other adjustments prior to
    the effective date.

    (2) Total number of Warrants to be outstanding on the Effective
    Date will vary depending on the predecessor warrant expiry,
    exercise or issue between the Agreement date and the Effective
    Date.

    (3) Total number of Options to be outstanding at closing of the
    Amalgamation will vary depending on the predecessor option expiry
    or exercise between the Agreement date and the Effective Date.

    (4) All outstanding share purchase warrants of the Partners will,
    at the Effective Date, be adjusted in accordance with the terms
    of the certificates representing such warrants, to equivalent
    amounts of Canada Gas Corp. warrants and exercise prices based
    upon the Share Exchange Ratios described above. The number of
    shares underlying each outstanding stock option of each of the
    Partners will also be adjusted using this methodology. Upon the
    Effective Date, Canada Gas Corp. will undertake to re-price the
    outstanding stock options and warrants described subject to
    regulatory approvals as well as the acceptance of the TSX Venture
    Exchange at either the future financing price or the five day
    trading average, provided that such undertaking will not be a
    condition to the Amalgamation.
    


    The Partners have proposed that the Board of Directors of Canada Gas
Corp. be comprised of 7 Directors including, a nominee from each of the
Partners and 3 nominees to be agreed upon by the Partners. The Partners are
evaluating opportunities for experienced oil and gas industry personnel to
join Canada Gas Corp. on the Board of Directors and as Management, although no
decisions have yet been made in this regard. The Partners are also in
discussions with interested investment firms respecting proposals for
financing Canada Gas Corp. concurrently with the closing of the amalgamation.
More information on this financing will be provided when available.
    Research Capital Corporation has been engaged to prepare an opinion as to
the fairness of the transaction, from a financial point of view, for the
shareholders of each of Wyn Developments Inc., Bighorn Petroleum Ltd. and
Flying A Petroleum Ltd. ahead of respective information circulars and
shareholders meetings on the transaction.
    The Partners are anticipating shareholder meetings on the transaction to
be held in mid November 2007, and the Canada Gas Corp. amalgamation to close
shortly thereafter, ahead of a productive winter 2007/2008 drill season,
barring any unforeseen delays.
    Dave McMillan, President, CEO, and Director of Wyn Developments Inc.
offers the following commentary in relation to the aforementioned items:

    "The partners continue working diligently to protect the
    investments of and create value for all shareholders. The reserve
    evaluations have been performed per industry standard and provide
    a starting point towards realizing the full potential of these
    natural gas assets. The numerous prospective development
    locations across these lands offer an attractive natural gas
    weighted growth model for investors moving forward. By combining
    the assets, attracting experienced oil and gas management,
    financing towards a sustainable growth model, and initiating an
    aggressive development plan, Canada Gas Corp. shareholders will
    benefit from a strong entity well positioned to realize this
    growth and seize upon new opportunities."


    
                       ABOUT CANADA GAS CORP.

    The Partners are currently active in three natural gas projects; the
Prophet River, Bougie Trutch, and Trutch East natural gas development
projects, all located in the Foothills region of the prolific natural gas
bearing Western Canadian Sedimentary Basin, northeastern British Columbia,
Canada. The Western Canadian Sedimentary Basin is home to many world-class oil
and gas fields, and features extensive logistical infrastructure. The combined
assets of Canada Gas Corp. will include:

    -   A combined revenue stream from existing wells in production.

    -   A 100% working interest in the Prophet River 'A' lands
        (approx. 11 square miles).

    -   A right to earn a 65% working interest in the Prophet River
        'B' lands (approx. 10 square miles).

    -   A 100% ownership of the Prophet River 'A' and 'B' land 3D
        seismic data.

    -   A 100% interest in the recently drilled d-60-E/94-G-15
        Prophet River well, which as previously announced, yielded an
        initial unstabilized gas flow of up to 7.943 MMcf.d. from the
        Mississippian Horizon and excellent gas detection in the
        Triassic Halfway Formation. This well has been confirmed a
        'new pool discovery' by the British Columbia Oil and Gas
        Commission.

    -   A 32.5% gross working interest in the Bougie Trutch and
        Trutch East lands, including a third party overriding
        royalty, subject to various terms.

    -   Milestone third party bonuses and stock payments from third
        parties for successful tie-in on the Trutch East lands.

    -   A 32.5% interest in 14,217 meters of six inch pipeline from
        the Tommy Lake field to the c-36-A well, and a total of
        1,688 meters of four inch pipeline from c-36-A to the b-56-A
        and c-25-A wells.

    -   A 32.5% gross working interest 5 Triassic Halfway Formation
        wells: Three Triassic Halfway wells producing since February
        2007, one well currently shut-in and another suspended until
        the 2007/2008 winter season's completion program.

    -   A combination of approximately $29 million in tax pools, plus
        government royalty and exploration credits.

    -   A British Columbia Oil and Gas Commission issued Operator's
        license.
    

    The transaction is subject to the parties completing final due diligence
and entering into a further definitive agreement providing for the specific
mechanics to complete the transaction, as well as all requisite regulatory,
court and shareholder approvals and acceptances, and the satisfaction of all
conditions precedent and other conditions customary in transactions of this
nature.
    Mr. Thomas W. Bainbridge P.Geol., is the qualified consultant for the
Company's natural gas projects and has reviewed and verified the contents of
this news release.
    Mr. A.J. Shah, P.Eng, of Reliance Engineering Group Ltd. has prepared
these reserves evaluations in compliance with national instrument 51-101
policy.
    For more information on the Partners, please visit
www.wyndevelopments.ca, www.bighornpetroleum.com and www.flyingapetroleum.com.

    
    On Behalf of the respective boards,

    WYN DEVELOPMENTS INC.          FLYING A PETROLEUM INC.

    "David McMillan"               "Nash Meghji"

    ------------------             ------------------
    David McMillan                 Nash Meghji
    President & CEO                President and CEO


    BIGHORN PETROLEUM LTD.         TENAKA DRILLING CONSORTIUM LTD.

    "Darren Stevenson"             "Alistair MacLennan"

    ------------------             ------------------
    Darren Stevenson               Alistair MacLennan
    President & CEO                President and CEO
    


    COMPANY CONTACT INFORMATION

    BIGHORN PETROLEUM LTD.
    Suite 605, 535 Howe Street
    Vancouver, B.C. Canada V6C 2Z4
    Tel: (604) 683-7837
    Fax: (604) 683-7881
    info@bighornpetroleum.com

    FLYING A PETROLEUM LTD.
    Penthouse, 535 Howe Street
    Vancouver, B.C. Canada V6C 2Z4
    Tel: (604) 683-0466
    Fax: (604) 685-8474
    Toll Free: (800) 665-3250
    info@flyingapetroleum.com

    TENAKA DRILLING CONSORTIUM LTD.
    Suite 718-744 West Hastings st.
    Vancouver, BC, Canada V6C 1A5
    Tel: (604) 684-1007
    Fax: (604) 684-3033
    alistair@urg.ca

    WYN DEVELOPMENTS INC.
    Wyn Developments Inc.
    520 - 700 West Pender Street
    Vancouver, BC, V6C 1G8
    (604) 685-5851 or Toll Free: (888) 685-5851
    Fax: (604) 685-7349
    Email: chad@urg.ca


    FORWARD-LOOKING STATEMENTS

    This press release may contain forward-looking statements including
expectations of future production. More particularly, this press release
contains statements concerning Wyn Developments Inc. future production
estimates, expansion of oil and gas property interests, exploration and
development drilling, regulatory applications, payout estimates, capital
expenditures, and drilling locations to be drilled in 2007. 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: 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 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 and environmental risks),
commodity price, price and exchange rate fluctuation and uncertainties
resulting from potential delays or changes in plans with respect to
exploration or development projects or capital expenditures. Additional
information on these and other factors that could affect Wyn's operations or
financial results are included in Wyn Developments' reports on file with
Canadian securities regulatory authorities. The forward-looking statements or
information contained in this news release are made as of the date hereof and
Wyn Developments 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. Oil and Gas Advisory. This press release contains disclosure
expressed as "boe". All oil and natural gas equivalency volumes have been
derived using the ratio of six thousand cubic feet of natural gas to one
barrel of oil. Equivalency measures may be misleading, particularly if used in
isolation. A conversion ratio of six thousand cubic feet of natural 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
well head. The TSX Venture Exchange has not reviewed and does not accept
responsibility for the adequacy or accuracy of this release.





For further information:

For further information: Chad McMillan/Dave McMillan, (604) 685-5851 or
Toll Free: (888) 685-5851, Email: chad@urg.ca

Organization Profile

WYN DEVELOPMENTS INC.

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BIGHORN PETROLEUM LTD.

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