Tourmaline Grows Year-End Reserves and Reserve Value by Over 40%; Increases 2014 Guidance

Tourmaline Grows Year-End Reserves and Reserve Value by Over 40%; Increases 
2014 Guidance 
FOR: Tourmaline Oil Corp. 
FEBRUARY 19, 2014 
Tourmaline Grows Year-End Reserves and Reserve Value by Over 40%; Increases
2014 Guidance 
CALGARY, ALBERTA--(Marketwired - Feb. 19, 2014) - Tourmaline Oil Corp.
(TSX:TOU) ("Tourmaline" or the "Company") is pleased to
provide the following operations and financial update and highlights from its
year-end 2013 independent reserve evaluation. 
Reserve Highlights 
--  Total year-end 2013 Proved plus Probable (2P) reserves of 590.1 mmboe 
after only five full years of operation. 
--  Total 2P reserve additions of 179.4 mmboe in 2013, representing 41% 
growth over 2012 total 2P reserves before 2013 production (30% per 
diluted share). 
--  Year-end 2013 2P reserve value of $6.2 billion (10% discount, before 
tax), representing 42% growth over year-end 2012 2P reserve value of $ 
4.3 billion, a net present value increase in 2013 of $1.9 billion vs. 
$1.7 billion in 2012. 
--  Year-end 2013 total corporate liquids (oil and natural gas liquids) 
reserves of 85.6 mmbbls represent a 67% increase over 2012 liquids 
--  2013 2P finding, development and acquisition costs (FD&A) of $11.84/boe 
including future development capital (FDC) and $7.33/boe excluding FDC. 
--  Three-year 2P FD&A of $11.65/boe (including FDC) and $7.20/boe 
(excluding FDC). 
--  2013 Recycle Ratio of 1.9 based on 2013 2P FD&A of $11.84/boe (including 
FDC) and 2014 forecast funds from operations per boe of $22.83. 
--  2013 reserve replacement ratio of 6.6 times. 
--  Peace River High Charlie Lake reserves were increased by 101% in 2013 
over 2012. 
--  Current 2P FDC represents 2.5 years of estimated future cash flow.  
Production Update 
--  Tourmaline exceeded its year-end 2013 exit production guidance of 
110,000 boepd, and expects to reach the 118,000 boepd production level 
in March 2014. 
--  Current full year 2014 average production guidance has been increased to 
120,000 boepd, representing approximately 60% growth over average 2013 
production of 74,796 boepd. 
--  Full year 2013 average production of 74,796 boepd represented a 47% 
increase over full year 2012 production of 50,804 boepd. 
--  Fourth quarter 2013 production averaged 86,089 boepd, a 50% increase 
over the fourth quarter 2012 average production rate of 57,230 boepd. 
--  Record fourth quarter liquids production of 11,700 bopd represented a 
74% increase over fourth quarter of 2012. 
--  Tourmaline expects to tie-in approximately 55 wells during the first 
quarter of 2014.  
EP Update 
--  Tourmaline is currently operating 17 drilling rigs, including 12 rigs in 
the Alberta Deep Basin complex, 2 rigs in the B.C. Montney gas 
condensate complex and 3 rigs in the Peace River High Charlie Lake oil 
complex. The Company now expects to operate 16 drilling rigs after 
break-up, up from 13 rigs in the original second half 2014 forecast. 
--  Tourmaline completed an acquisition in December adjacent to the 
Company's recent new Montney gas condensate discovery for $71.1 million. 
The acquisition added approximately 900 bopd of new production and 
approximately 55 new horizontal Montney locations. 
--  Charlie Lake reserves on the Peace River High were increased to 49.75 
mmboe, a 101% increase over 2012 reserves of 24.75 mmboe. Tourmaline 
expended $53.0 million in 2013 consolidating land on this new regional 
oil play, and in aggregate 514 sections were acquired on the trend. The 
Company believes that the regional pool could ultimately yield in excess 
of 500 mmboe, the Company controls over 75% of the prospective trend as 
currently mapped. The Company plans to complete four concurrently 
stimulated horizontal well pairs prior to break-up. 
--  The Company's Paleozoic exploratory well at Sunset B.C. has been cased 
to TD and will be completed prior to break-up. 
--  The Company's initial drilling program in the Alberta Deep Basin Montney 
trend has resulted in two vertical and one horizontal gas well in the 
Smoky-Resthaven-Kakwa areas thus far. All three wells will be completed 
and tested prior to break-up. The Company has over 100 sections of 
Montney rights in the northern portion of the Deep Basin core area.  
Financial Update 
--  The total 2013 cash consideration invested in capital expenditures, net 
of dispositions was $ 1,315.4 million including $ 43.0 million for new 
lands and $ 386.6 million for facilities and pipelines (approximately 
32.7% of the total cash capital expenditures). 
--  With completion of the equity financing during the first quarter of 
2014, Tourmaline is expanding the 2014 capital budget to $1.0 billion 
from $900 million, and increasing full year 2014 average production 
guidance to 120,000 boepd. 
--  Tourmaline is expecting 2014 funds from operations in excess of $1.0 
billion based on an AECO natural gas price of $3.86/mcf, an increase of 
approximately 90% over 2013.  
Summary of Oil and Gas Reserves                       
And Net Present Values of Future Net Revenue                 
As of December 31, 2013 Forecast Prices and Costs              
RESERVES SUMMARY                                                             
Light & Medium Oil        Natural Gas      
Company    Company    Company    Company 
Gross        Net      Gross        Net
Reserves Category                   (Mbbls)    (Mbbls)     (MMcf)     (MMcf)
Proved Developed Producing            3,667      2,872    631,986    565,592
Proved Developed Non-Producing          930        791     54,385     48,959
Proved Undeveloped                    8,731      6,763    936,637    840,267
Total Proved                         13,329     10,426  1,623,008  1,454,818
Total Probable                       13,631     10,417  1,403,117  1,234,509
Total Proved Plus Probable           26,960     20,844  3,026,125  2,689,327 
Summary of Oil and Gas Reserves                       
And Net Present Values of Future Net Revenue                 
As of December 31, 2013 Forecast Prices and Costs              
RESERVES SUMMARY                                                             
Natural Gas Liquids  Total Oil Equivalent  
Company    Company    Company    Company 
Gross        Net      Gross        Net
Reserves Category                   (Mbbls)    (Mbbls)    (Mbbls)    (Mbbls)
Proved Developed Producing           13,191     10,429    122,189    107,566
Proved Developed Non-Producing        1,119        918     11,113      9,869
Proved Undeveloped                   18,168     15,041    183,005    161,848
Total Proved                         32,478     26,387    316,308    279,283
Total Probable                       26,112     20,942    273,596    237,111
Total Proved Plus Probable           58,590     47,329    589,904    516,394 
Company Gross reserves are defined as the working interest share of reserves
prior to the deduction of interest owned by others (burdens). Royalty interest
reserves are not included in Company Gross reserves. Company Net reserves are
defined as the working, net carried, and royalty interest reserves after
deduction of all applicable burdens. 
Net Present Values of Future Net Revenue ($000s)    
Before Future Income Taxes Discounted At (%/year)   
Reserves Category             0%         5%        10%        15%        20%
Proved Developed                                                            
 Producing             2,779,057  2,240,278  1,895,605  1,657,092  1,482,098
Proved Developed Non-                                                       
 Producing               279,546    215,341    176,736    151,050    132,697
Proved Undeveloped     3,676,325  2,445,553  1,741,193  1,295,977    993,673
Total Proved           6,734,928  4,901,172  3,813,534  3,104,119  2,608,467
Total Probable         6,774,423  3,745,904  2,375,651  1,639,449  1,196,359
Total Proved Plus                                                           
 Probable             13,509,351  8,647,075  6,189,185  4,743,568  3,804,826 
Unit Value Before   
Income Tax       
Discounted at 10%/year
Reserves Category                                         ($/boe)   ($/Mcfe)
Proved Developed                                                            
 Producing                                                  17.62       2.94
Proved Developed Non-                                                       
 Producing                                                  17.91       2.98
Proved Undeveloped                                          10.76       1.79
Total Proved                                                13.65       2.28
Total Probable                                              10.02       1.67
Total Proved Plus                                                           
 Probable                                                   11.99       2.00 
Net Present Values of Future Net Revenue ($000s)    
After Future Income Taxes Discounted At (%/year)   
Reserves Category             0%         5%        10%        15%        20%
Proved Developed                                                            
 Producing             2,779,057  2,240,278  1,895,605  1,657,092  1,482,098
Proved Developed Non-                                                       
 Producing               279,546    215,341    176,736    151,050    132,697
Proved Undeveloped     2,846,061  1,900,303  1,353,442  1,004,305    765,184
Total Proved           5,904,664  4,355,922  3,425,783  2,812,447  2,379,979
Total Probable         5,091,389  2,780,002  1,732,747  1,171,411    835,480
Total Proved Plus                                                           
 Probable             10,996,053  7,135,924  5,158,530  3,983,858  3,215,459 
Total Future Net Revenue ($000s) (Undiscounted)               
As of December 31, 2013 Forecast Prices and Costs              
Operating   Development
Reserves Category          Revenue     Royalties         Costs         Costs
Proved Producing         4,605,451       579,305     1,190,166             2
Proved Developed                                                            
 Nonproducing              466,683        57,716       106,143        21,356
Proved Undeveloped       7,576,785       950,509     1,197,441     1,721,691
Total Proved            12,648,919     1,587,530     2,493,750     1,743,049
Total Probable          12,436,375     1,775,109     2,391,086     1,453,369
Total Proved Plus                                                           
 Probable               25,085,294     3,362,639     4,884,837     3,196,418 
Total Future Net Revenue ($000s) (Undiscounted)               
As of December 31, 2013 Forecast Prices and Costs              
Future Net                             
Abandonment        Before                      Future 
and     Deducting        Future   Net Revenue 
Reclamation Future Income        Income  After Future
Reserves Category            Costs         Taxes         Taxes  Income Taxes
Proved Producing            56,921     2,779,057             -     2,779,057
Proved Developed                                                            
 Nonproducing                1,922       279,546             -       279,546
Proved Undeveloped          30,819     3,676,325       830,264     2,846,061
Total Proved                89,662     6,734,928       830,264     5,904,664
Total Probable              42,388     6,774,423     1,683,034     5,091,389
Total Proved Plus                                                           
 Probable                  132,049    13,509,351     2,513,299    10,996,053 
Crude Oil and Natural Gas Liquids                      
Price Forecast                                
As of January 1, 2014                            
Alberta Natural  
Gas Liquids    
Bank of                                                
Noon      WTI                               Edmonton 
Exchange  Cushing  Edmonton Edmonton Edmonton Pentanes 
Inflation   Rate   Oklahoma Par Price Propane   Butane    Plus   
Year        %     $US/$Cdn  $US/bbl  $Cdn/bbl $Cdn/bbl $Cdn/bbl $Cdn/bbl
 2014 Full                                                                   
Year       2.0     0.950     97.50    92.76    57.83    73.22    105.20  
2015       2.0     0.950     97.50    97.37    58.42    75.95    107.11  
2016       2.0     0.950     97.50    100.00   60.00    78.00    107.00  
2017       2.0     0.950     97.50    100.00   60.00    78.00    107.00  
2018       2.0     0.950     97.50    100.00   60.00    78.00    107.00  
2019       2.0     0.950     97.50    100.00   60.00    78.00    107.00  
2020       2.0     0.950     98.54    100.77   60.46    78.60    107.82  
2021       2.0     0.950    100.51    102.78   61.67    80.17    109.97  
2022       2.0     0.950    102.52    104.83   62.90    81.77    112.17  
2023       2.0     0.950    104.57    106.93   64.16    83.40    114.41  
2024+       2.0     0.950   +2.0%/yr  +2.0%/yr +2.0%/yr +2.0%/yr +2.0%/yr 
Natural Gas                                 
Price Forecast                               
As of January 1, 2014                            
Midwest        AECO/NIT        SUMAS      
NYMEX        @ Chicago         Spot           Spot      
Year        $US/MMBtu      $US/MMBtu      $Cdn/MMBtu     $US/MMBtu   
 2014 Full Year      4.25           4.35           4.03           4.20      
2015           4.50           4.60           4.26           4.45      
2016           4.75           4.85           4.50           4.70      
2017           5.00           5.10           4.74           4.95      
2018           5.25           5.35           4.97           5.20      
2019           5.50           5.60           5.21           5.45      
2020           5.63           5.73           5.33           5.58      
2021           5.74           5.84           5.44           5.69      
2022           5.86           5.96           5.55           5.81      
2023           5.97           6.07           5.66           5.92      
2024+         +2.0%/yr       +2.0%/yr       +2.0%/yr       +2.0%/yr    
FD&A          FD&A                                 
Including     Excluding   F&D Including F&D Excluding 
Changes in    Changes in    Changes in    Changes in  
FDC           FDC           FDC           FDC     
2013                     $/boe         $/boe         $/boe         $/boe    
Proved                   $17.52        $13.91        $18.24        $13.68   
Proved Plus Probable     $11.84        $7.33         $12.94        $7.38     
FD&A          FD&A                                 
Including     Excluding   F&D Including F&D Excluding 
Changes in    Changes in    Changes in    Changes in  
FDC           FDC           FDC           FDC     
2012                     $/boe         $/boe         $/boe         $/boe    
Proved                   $14.06        $9.11         $12.61        $8.21    
Proved Plus Probable     $10.35        $5.80         $8.87         $5.29     
FD&A          FD&A                                
2011-2013              Including     Excluding   F&D Including F&D Excluding 
Changes in    Changes in    Changes in    Changes in 
Weighted                  FDC           FDC           FDC           FDC     
Average                  $/boe         $/boe         $/boe         $/boe    
Proved                   $16.58        $12.54        $16.07        $12.16   
Proved Plus Probable     $11.65        $7.20         $11.32        $6.86     
Reader Advisories 
All amounts in this news release are stated in Canadian dollars unless
otherwise specified. 
Reserves Data 
The reserves data set forth above is based upon the reports of GLJ Petroleum
Consultants Ltd. ("GLJ") and Deloitte LLP, each dated effective
December 31, 2013, which have been consolidated into one report by GLJ and
adjusted to apply certain of GLJ's assumptions and methodologies and
pricing and cost assumptions. The complete GLJ January 1, 2014 price forecast
used in the reserve evaluations is available on its website at
The consolidated report includes 100% of the reserves and future net revenue
attributable to the properties of Exshaw Oil Corp, a subsidiary of the Company,
without reduction to reflect the 9.4% third-party minority interest in Exshaw. 
There are numerous uncertainties inherent in estimating quantities of crude
oil, natural gas and natural gas liquids (NGL) reserves and the future cash
flows attributed to such reserves. The reserve and associated cash flow
information set forth above are estimates only. In general, estimates of
economically recoverable crude oil, natural gas and NGL reserves and the future
net cash flows therefrom are based upon a number of variable factors and
assumptions, such as historical production from the properties, production
rates, ultimate reserve recovery, timing and amount of capital expenditures,
marketability of oil and natural gas, royalty rates, the assumed effects of
regulation by governmental agencies and future operating costs, all of which
may vary materially. For those reasons, estimates of the economically
recoverable crude oil, NGL and natural gas reserves attributable to any
particular group of properties, classification of such reserves based on risk
of recovery and estimates of future net revenues associated with reserves
prepared by different engineers, or by the same engineers at different times,
may vary. The Company's actual production, revenues, taxes and development
and operating expenditures with respect to its reserves will vary from
estimates thereof and such variations could be material. 
All evaluations and reviews of future net revenue are stated prior to any
provisions 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. The after-tax net present value of the Company's oil
and gas properties reflects the tax burden on the properties on a stand-alone
basis and utilizes the Company's tax pools. It does not consider the
corporate tax situation, or tax planning. It does not provide an estimate of
the after-tax value of the Company, which may be significantly different. The
Company's financial statements and the management's discussion and
analysis should be consulted for information at the level of the Company. 
The estimates of reserves and future net revenue for individual properties may
not reflect the same confidence level as estimates of reserves and future net
revenue for all properties, due to effects of aggregations. The estimated
values of future net revenue disclosed in this press release do not represent
fair market value. There is no assurance that the forecast prices and cost
assumptions used in the reserve evaluations will be attained and variances
could be material. 
The reserve data provided in this news release presents only a portion of the
disclosure required under National Instrument 51-101. All of the required
information will be contained in the Company's Annual Information Form for
the year ended December 31, 2013, which will be filed on SEDAR (accessible at on or before March 31, 2014. 
Unaudited Financial Information 
Certain financial and operating results included in this news release such as
finding, development and acquisition costs, finding and development costs,
recycle ratio, funds from operations, capital expenditures,  and production
information are based on unaudited estimated results. These estimated results
are subject to change upon completion of the audited financial statements for
the year ended December 31, 2013, and changes could be material. Tourmaline
anticipates filing its audited financial statements and related
management's discussion and analysis for the year ended December 31, 2013
on SEDAR on or before March 31, 2014. 
Per share reserve information is based on the total common shares outstanding,
after accounting for outstanding Company options, at year end 2013 and 2012,
Non-IFRS Financial Measures 
This press release includes references to financial measures commonly used in
the oil and gas industry such as "funds from operations", and
"recycle ratio" which do not have any standardized meaning prescribed
by International Financial Reporting Standards ("IFRS"). Management
believes that in addition to net income and cash flow from operating
activities, these non-IFRS financial measures are useful supplemental measures
in assessing Tourmaline's ability to generate the cash necessary to repay
debt or fund future growth through capital investment. Readers are cautioned,
however, that these measures should not be construed as an alternative to net
income or cash flow from operating activities determined in accordance with
IFRS as an indication of Tourmaline's performance. Tourmaline's
method of calculating these measures may differ from other companies and
accordingly, they may not be comparable to measures used by other companies.
For these purposes, Tourmaline defines funds from operations as cash provided
by operations before changes in non-cash operating working capital and defines
recycle ratio as estimated 2014 funds from operations per boe divided by 2013
FD&A (including FDC) per boe.  
BOE Equivalency 
In this press release, production and reserves information may be presented on
a "barrel of oil equivalent" or "BOE" basis. 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. In addition, as the value ratio between natural gas and crude oil
based on the current prices of natural gas and crude oil 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. 
F&D and FD&A Costs 
In addition to F&D, the Company uses FD&A as a measure of the
efficiency of its overall capital program including the effect of acquisitions
and dispositions. 
The aggregate of the exploration and development costs incurred in the most
recent financial year and the change during that year in estimated future
development costs generally will not reflect total finding and development
costs related to reserves additions for that year. 
Forward-Looking Information 
This press release contains forward-looking information within the meaning of
applicable securities laws. The use of any of the words "expect",
"forecast", "anticipate", "continue",
"estimate", "objective", "ongoing",
"may", "will", "project", "should",
"believe", "plans", "intends" and similar
expressions are intended to identify forward-looking information. More
particularly and without limitation, this press release contains forward
looking information concerning Tourmaline's plans and other aspects of its
anticipated future operations, management focus, objectives, strategies,
financial, operating and production results and business opportunities
including estimated and future anticipated 2014 funds from operations and funds
from operations per boe, estimated volumes and value of oil and gas reserves
and production volume estimates, future oil and natural gas prices, operating
costs and production efficiencies as well as Tourmaline's future drilling
and completion prospects and plans, including the number and type of wells to
be drilled in core areas, business strategy, future development and growth
opportunities, prospects and asset base. The forward-looking information is
based on certain key expectations and assumptions made by Tourmaline, including
expectations and assumptions concerning: prevailing commodity prices and
currency exchange rates; interest rates; applicable royalty rates and tax laws;
future well production rates and reserve volumes; the timing of receipt of
regulatory approvals which include tie-in approvals; the performance of
existing wells and recently drilled and tested wells; the success obtained in
drilling new wells; the sufficiency of budgeted capital expenditures in
carrying out planned activities; the availability and cost of labour and
services, the state of the economy and the exploration and production business;
the availability and cost of financing; and ability to market oil and natural
gas successfully.  Statements relating to "reserves" are also deemed
to be 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 that the reserves can be profitably
produced in the future. 
Undue reliance should not be placed on the forward-looking information because
Tourmaline can give no assurances that it will prove to be correct. Since
forward-looking information addresses future events and conditions, by its very
nature it involves inherent risks and uncertainties. Actual results could
differ materially from those currently anticipated due to a number of factors
and risks. These include, but are not limited to: the risks associated with the
oil and gas industry in general such as 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
estimates and projections relating to reserves, production, revenues, costs and
expenses; health, safety and environmental risks; commodity price, currency
exchange rate and interest rate fluctuations; marketing and transportation;
loss of markets; environmental risks; competition; incorrect assessment of the
value of acquisitions; failure to realize the anticipated benefits of
acquisitions; ability to access sufficient capital from internal and external
sources; failure to obtain required regulatory and other approvals; and changes
in legislation, including but not limited to tax laws, royalties and
environmental regulations. Readers are cautioned that the foregoing list of
factors is not exhaustive. 
Also included in this press release are estimates of Tourmaline's 2014
funds from operations per boe, which is based on Tourmaline's estimated
2014 funds from operations of $1 billion and average production of 120,000
boepd. Tourmaline's estimated 2014 funds from operations is based on the
various assumptions as to production levels, capital expenditures, and other
assumptions disclosed in this press release and including commodity price
assumptions for natural gas (AECO - $3.86/mcf) (2014), and crude oil (WTI (US)
- $97.00/bbl) (2014) and an exchange rate assumption of $0.97 (US/CAD) for
2014. To the extent such estimate constitutes a financial outlook, it was
approved by management and the Board of Directors of Tourmaline on February 19,
2014 and is included to provide readers with an understanding of
Tourmaline's anticipated funds from operations based on the capital
expenditure and other assumptions described herein and readers are cautioned
that the information may not be appropriate for other purposes. 
Additional information on these and other factors that could affect Tourmaline,
or its operations or financial results, can be found in Tourmaline's most
recent Annual Information Form and Annual and Quarterly Management's
Discussion and Analysis on file with applicable securities regulatory
authorities and may be accessed through the SEDAR website ( or
Tourmaline's website ( 
The forward-looking information contained in this press release is made as of
the date hereof and Tourmaline undertakes no obligation to update publicly or
revise any forward-looking information, whether as a result of new information,
future events or otherwise, unless expressly required by applicable securities
Certain Definitions: 
bbls       barrels                                           
boe        barrel of oil equivalent                          
boepd      barrel of oil equivalent per day                  
bopd       barrel of oil, condensate or liquids per day      
mmboe      millions of barrel of oil equivalent              
mbbls      thousand barrels                                  
mcf        thousand cubic feet                               
mmcf       million cubic feet                                
mmcfpd     million cubic feet per day                        
mcfe       thousand cubic feet equivalent                    
mmbtu      million British thermal units                      
About Tourmaline Oil Corp. 
Tourmaline is a Canadian intermediate crude oil and natural gas exploration and
production company focused on long-term growth through an aggressive
exploration, development, production and acquisition program in the Western
Canadian Sedimentary Basin. 
Tourmaline Oil Corp.
Michael Rose
Chairman, President and Chief Executive Officer
(403) 266-5992
Tourmaline Oil Corp.
Brian Robinson
Vice President, Finance and Chief Financial Officer
(403) 767-3587
Tourmaline Oil Corp.
Scott Kirker
Secretary and General Counsel
(403) 767-3593
Tourmaline Oil Corp.
Suite 3700, 250 - 6th Avenue S.W.
Calgary, Alberta  T2P 3H7
(403) 266-5992
(403) 266-5952 
INDUSTRY:  Energy and Utilities - Oil and Gas  
-0- Feb/19/2014 22:00 GMT
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