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CYGAM Announces 2013 Year-End Reserves

CALGARY, ALBERTA -- (Marketwired) -- 02/26/14 -- CYGAM Energy Inc. (TSX VENTURE:CYG) ("CYGAM", or the "Company"), an emerging oil and gas company with interests in Tunisia and Italy, announced today that InSite Petroleum Consultants Ltd. of Calgary, Alberta, ("InSite") has completed the annual update to CYGAM's Reserve Report for the Bir Ben Tartar Concession ("the Concession") in the Sud Remada Permit in Tunisia, effective December 31, 2013 (the "Report"). The Report was prepared in accordance with National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities ("NI 51-101") and the Canadian Oil and Gas Evaluation Handbook ("COGEH"). The report is based on InSite's review of technical data including geology, geophysics and reservoir. CYGAM holds a 14% interest in the Concession which contains the TT Field and a 14% interest in the Sud Remada Permit.

The Company's production from the Concession is governed by a production sharing agreement ("PSA") with ETAP, the Tunisian national oil company. All amounts set forth herein relate to CYGAM's net share, after ETAP participation and taxes, and are reported in Canadian dollars.

Year-End 2013 Reserves

Based on a static, volumetric geological model developed by a third party, InSite evaluated the total TT Field to contain an estimated total Discovered Petroleum Initially in Place ("DPIIP") of 201.7 million barrels, which is unchanged from December 31, 2012.

The following summarizes the changes in CYGAM's net reserves:


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                                       December 31,   December 31,          
Oil Reserves (barrels)                      2013(1)        2012(2) Increase 
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Proved                                      472,600        430,200       10%
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Proved plus Probable                        891,600        807,100       10%
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Proved plus Probable plus Possible        1,320,000      1,180,100       12%
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1.  Information derived from the Report. 
2.  Information derived from a report (the "2012 Report") prepared by InSite
    effective December 31, 2012, which was prepared in accordance with NI
    51-101 and COGEH. 

Following 2013 net CYGAM production of 83,067 barrels, reserves replacement ratios are as follows:


----------------------------------------------------------------------------
Proved                                       151%                           
----------------------------------------------------------------------------
Proved plus Probable                         203%                           
----------------------------------------------------------------------------
Proved plus Probable plus Possible           268%                           
----------------------------------------------------------------------------

Estimated Future Net Revenues

All evaluations and reviews of future net cash flows are stated prior to any provision for interest costs or general and administrative costs and after the deduction of estimated future capital expenditures for wells to which reserves have been assigned.


----------------------------------------------------------------------------
                                                  Future Net Revenue        
                                             (after ETAP and taxes)(1) (2)  
----------------------------------------------------------------------------
                              Net Remaining                                 
Reserve     Gross Remaining Reserves (after                                 
 Category          Reserves        ETAP)(1) Undiscounted     5%          10%
----------------------------------------------------------------------------
                  (barrels)       (barrels)         (M$)   (M$)         (M$)
----------------------------------------------------------------------------
                                                                            
----------------------------------------------------------------------------
Proved                                                                      
 Developed        2,285,900         191,200       10,754  9,944        9,246
----------------------------------------------------------------------------
Proved                                                                      
 Undeveloped      3,363,800         281,400       10,539  8,014        6,106
----------------------------------------------------------------------------
 Total                                                                      
  Proved          5,649,700         472,600       21,293 17,958       15,352
----------------------------------------------------------------------------
                                                                            
----------------------------------------------------------------------------
Probable          5,567,100         419,000       23,002 17,321       13,271
----------------------------------------------------------------------------
 Total                                                                      
  Proved +                                                                  
  Probable       11,216,800         891,600       44,295 35,279       28,623
----------------------------------------------------------------------------
                                                                            
----------------------------------------------------------------------------
Possible          7,032,600         428,400       26,159 17,510       12,242
----------------------------------------------------------------------------
 Total                                                                      
  Proved +                                                                  
  Probable +                                                                
  Possible       18,249,400       1,320,000       70,454 52,789       40,865
----------------------------------------------------------------------------

1.  Under the PSA, the Company receives a share of the production under a
    sliding scale formula. The calculation includes a cost oil component
    which enables the Company to recover all of its costs and a profit
    sharing component whereby profits are split between the Company and
    ETAP. In addition, ETAP is responsible for paying all income taxes
    arising from production from the Concession. 
2.  It should not be assumed that the estimates of future net revenues
    presented herein represent the fair market value of the reserves. 

Changes in the Net Present Value ("NPV") of future net revenues are summarized below:


----------------------------------------------------------------------------
NPV (M$)        December 31, 2013(1) December 31, 2012(2)      Increase     
                ------------------------------------------------------------
                Undiscounted   NPV10 Undiscounted   NPV10 Undiscounted NPV10
----------------------------------------------------------------------------
Proved                21,293  15,352       19,370  14,410         9.9%  6.5%
----------------------------------------------------------------------------
Proved +                                                                    
 Probable             44,295  28,623       38,402  25,720        15.3% 11.3%
----------------------------------------------------------------------------
Proved +                                                                    
 Probable+Possib                                                            
 le                   70,454  40,865       60,223  37,385        17.0%  9.3%
----------------------------------------------------------------------------

1.  Information derived from the Report. 
2.  Information derived from the 2012 Report. 

Crude produced from the TT Field sells at close to Brent prices. Future revenues in the Report were estimated using the following price forecast for Brent crude:


----------------------------------------------------------------------------
                                2014      2015      2016      2017      2018
----------------------------------------------------------------------------
C$/barrel (1)                 110.53    107.89    105.47    102.84    103.16
----------------------------------------------------------------------------

1.  Assumes exchange rate US$1.00 = C$1.05. 

Contingent Resources

In the Report reserves have only been assigned to a portion of the mapped field area with the remaining field areas classified as contingent resources:


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                                   Gross Contingent                         
                                         Resources        Company Contingent
Resource Category                            (bbls)         Resources (bbls)
----------------------------------------------------------------------------
Low                                      10,816,000                  782,300
----------------------------------------------------------------------------
Best                                     13,520,000                  977,900
----------------------------------------------------------------------------
High                                     18,026,000                1,303,800
----------------------------------------------------------------------------

Because of uncertainty of commerciality, the estimated Contingent resources cannot be classified as reserves as of the effective date of this report. Uncertainties include - but are not limited to - insufficient delineation of the discovered oil and gas accumulation as well as a lack of demonstrated funding. The Contingent resource estimates are provided as a means of comparison to other Contingent resources and are not to be directly compared to reserves. There is no certainty that it will be commercially viable to produce any portion of the resources and the economic status of contingent resources summarized in this report is undetermined.

The Report was prepared by InSite, an independent international petroleum consulting firm registered in the province of Alberta. Summary data from the Report will be filed on the Company's SEDAR profile at www.sedar.com on or around March 7, 2014 and will also be available on the Company's website at www.cygamenergy.com. CYGAM recommends that readers refer to the summary data as it details the process for determining the reserve estimates, the assumptions underpinning the modeling, and defines technical terms used.

"Additional data from wells drilled in 2013 together with longer production history has increased our knowledge of the property and it is gratifying that we have more than replaced production over the past year," said David Taylor, President and CEO of CYGAM. "The joint venture has now embarked on a third phase of development drilling with six vertical wells planned to be completed and put on production during the first half of 2014."

About InSite Petroleum Consultants Ltd.

InSite is a Calgary based petroleum consulting firm who specialize in evaluation of reserves and resources for domestic and international oil and gas companies, governments, financial institutions and the investment industry. For more detail on InSite, please visit their website, at: www.insitepc.com.

About CYGAM Energy Inc.

CYGAM is a Calgary based exploration company with extensive international exploration permits and a producing property in Tunisia. The main focus of CYGAM is the acquisition, exploration and development of international oil and gas permits, primarily in Italy, Tunisia and the Mediterranean Basin. CYGAM currently holds various interests in five exploratory permits in Italy plus three exploratory permits and the BBT Production Concession in Tunisia which together encompass a total of approximately 2.5 million gross acres.

Cautionary Statements

In the interest of providing shareholders and potential investors with information regarding CYGAM, including management's assessment of the future plans and operations of CYGAM, certain statements contained in this news release constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of applicable securities legislation. In particular, this news release contains, without limitation, forward-looking statements pertaining to: future drilling operations; production and reserve growth; reserve, resource and future net revenue estimates; and the filing of the summary data from the Report.

With respect to the forward-looking statements contained in this news release, CYGAM has made assumptions regarding, among other things: the ability of the Operator to continue to operate in Tunisia with limited logistical, security and operational issues; the ability of the Operator to obtain equipment in a timely manner to carry out drilling and completion operations; the results of geological, geophysical and reservoir analysis and testing operations; commodity prices; the receipt of required regulatory approvals; global economic conditions. Although CYGAM believes that the expectations reflected in the forward-looking statements contained in this news release, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this news release, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements will not occur, which may cause CYGAM's actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements.

These risks and uncertainties include, without limitation: political and security risks associated with the Operator's Tunisian operations, risks associated with oil and gas exploration, development, exploitation, production, marketing and transportation, loss of markets, volatility of commodity prices, currency fluctuations, imprecision of reserve and resource estimates, results of geological, geophysical and reservoir analysis and testing operations, the inability to retain drilling rigs and other services, capital expenditure costs, including drilling, completion and facilities costs, unexpected decline rates in wells, delays in projects and/or operations, wells not performing as expected, delays resulting from or inability to obtain the required regulatory approvals, CYGAM's ability to access sufficient capital from internal and external sources, results of seismic and drilling operations; and risks associated with the operation of CYGAM's assets by third parties, including the limited ability of CYGAM to exercise influence over the operation of those assets or their associated costs, the timing and amount of capital expenditures, the operator's expertise and financial resources, the approval of other participants, and the selection of technology and risk management practices. As a consequence, actual results may differ materially from those anticipated in the forward-looking statements. Readers are cautioned that the forgoing list of factors is not exhaustive. Additional information on these and other factors that could affect CYGAM's operations and financial results are included in reports on file with Canadian securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com). Furthermore, the forward-looking statements contained in this news release are made as at the date of this news release and CYGAM does not undertake any obligation to update publicly or to revise any of the forward-looking statements, whether as a result of new information, future events or otherwise, except as may be required by applicable securities laws.

All "total oil in place" other than, cumulative production, reserves and contingent resources has been categorized as undiscovered.

Definitions of Reserves Categories:


--  "Proved" reserves are those reserves that can be estimated with a high
    degree of certainty to be recoverable. It is likely that the actual
    remaining quantities recovered will exceed the estimated proved
    reserves. 
    
--  "Probable" reserves are those additional reserves that are less certain
    to be recovered than proved reserves. It is equally likely that the
    actual remaining quantities recovered will be greater or less than the
    sum of the estimated proved plus probable reserves. 
    
--  "Possible" reserves 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 proved
    plus probable plus possible reserves. 

"Contingent Resources" are those quantities of oil estimated, as of a given date, to be potentially recoverable from known accumulations using established technology or technology under development, but which are not currently considered to be commercially recoverable due to one or more contingencies. Contingencies may include factors such as distance from existing production, economic, legal, environmental, political, and regulatory matters or a lack of markets. Some of the specific contingencies identified by InSite to convert contingent resources into reserves include, without limitation, insufficient delineation of the discovered oil and gas accumulation as well as a lack of demonstrated funding. It is also appropriate to classify as contingent resources the estimated discovered recoverable quantities associated with a project in the early evaluation stage. Contingent resources are further classified in accordance with the level of certainty associated with the estimates and may be sub classified based on project maturity and/or characterized by their economic status.

Uncertainty Ranges are described by the COGEH as low, best, and high estimates for reserves and resources as follows:

Low Estimate: This is considered to be a conservative estimate of the quantity that will actually be recovered. It is likely that the actual remaining quantities recovered will exceed the low estimate. If probabilistic methods are used, there should be at least a 90 percent probability (P90) that the quantities actually recovered will equal or exceed the low estimate.

Best Estimate: This is considered to be the best estimate of the quantity that will actually be recovered. It is equally likely that the actual remaining quantities recovered will be greater or less than the best estimate. If probabilistic methods are used, there should be at least a 50 percent probability (P50) that the quantities actually recovered will equal or exceed the best estimate.

High Estimate: This is considered to be an optimistic estimate of the quantity that will actually be recovered. It is unlikely that the actual remaining quantities will exceed the high estimate. If probabilistic methods are used, there should be at least a 10 percent probability (P10) that the quantities actually recovered will equal or exceed the high estimate.

The "reserves replacement ratio" is determined by dividing the yearly change in reserves before production by the actual annual production for the year (eg Total Proved plus Probable (((807,100-547,100)+89,762)/89,762=3.9).

Disclosure provided herein in respect of BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 Mcf: 1 Bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.

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

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