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Press release from CNW Group

Tourmaline Oil Corp. Reports Q3 2012 Financial Results

Thursday, November 08, 2012

Tourmaline Oil Corp. Reports Q3 2012 Financial Results17:08 EST Thursday, November 08, 2012INCREASES 2012 EXIT AND 2013 PRODUCTION GUIDANCE AND EXPANDS CAPITAL PROGRAMCALGARY, Nov. 8, 2012 /CNW/ - Tourmaline Oil Corp. (TSX:TOU) ("Tourmaline" or the "Company") is pleased to report strong Q3 2012 results and increased production guidance for exit 2012 and 2013.  The Company has embarked upon an accelerated growth plan in all three core-operated areas through an expanded 2H 2012/2013 EP capital program and complementary accretive acquisitions.Q3 2012 HighlightsPrevious 2012 exit production guidance levels achieved in October2013 average production guidance increased to 75,000 boepd including announced acquisitions2012 exit production guidance increased to 63,000 - 65,000 boepd2012 and 2013 EP capital programs increasedComplementary acquisitions in two of the Company's three core-operated areas that are expected to close prior to year endThird quarter 2012 operating costs of $3.66/boeMusreau Alberta plant expansion completed in SeptemberSeveral successful Spirit River Charlie Lake pool expansion horizontals completedProduction UpdateProduction levels have reached the Company's previously upwards-revised 2012 exit guidance levels of 55,000 - 56,500 boepd. These production levels do not include production associated with the announced acquisitions. The Company remains on track to achieve full-year 2012 average production in excess of 50,000 boepd; guidance for the year was increased during Q1 2012 from 47,000 to 50,000 boepd.Third quarter production of 48,175 boepd represented an increase of 40% over third quarter 2011 production of 34,347 boepd. Third quarter production was negatively impacted primarily by facility-related unscheduled down-time at Spirit River, Alberta and Sunrise, B.C.  Sour-associated gas handling issues resulted in liquid production losses at Spirit River of approximately 900 bpd for the quarter. At Sunrise, an equipment failure in the refrigeration plant resulted in approximately 500 boepd of production losses. The Sunrise plant disruption was remedied during the third quarter and was a one-time equipment issue; the Spirit River gas-handling issues are being remedied by a gas facility expansion that is already underway and expected to be completed during the first quarter of 2013. Weather delayed tie-in of several wells throughout the EP portfolio during the third quarter. Third quarter production was positively impacted by the completion of the Musreau plant expansion in the second half of September, which has allowed the Company to meet 2012 exit production guidance ahead of schedule. Assuming closing of the Huron and Deep Basin acquisitions prior to year end, the 2012 exit production estimate has been increased to 63,000 - 65,000 boepd.The Company is now estimating 2013 average production of 75,000 boepd, including the impact of the Huron acquisition, which is anticipated to close in late November 2012, and the Deep Basin asset acquisition that closed on November 7, 2012.Cost StructureThird quarter operating costs of $3.66 /boe were significantly lower than forecast - 24% lower than Q2 2012 costs of $4.83/boe and 37% lower than third quarter of 2011.Third quarter cash G&A per boe costs were $0.79/boe, a 16% reduction from third quarter 2011, and amongst the lowest in the industry. The Company will continue the focus on reducing costs in all aspects of its EP business.Capital ProgramsThe 2H 2012 capital program was expanded in conjunction with the equity financing in August. The ongoing drilling program was expanded from six to eight rigs in July and new facility projects were initiated in the third quarter, primarily at Spirit River and Sunrise-Dawson. Outside operated drilling in the Alberta Deep Basin also accelerated with six additional horizontals drilled and/or completed in the third quarter. Full year EP capital spending of $525.0 million is expected, not including acquisitions. The Company is planning to run an eight-to-nine rig program through until spring break-up 2013. Year end 2012 debt of $353.1 million is currently anticipated, including the Deep Basin acquisition for cash and assumption of Huron Energy's net debt (approximately $24 MM). This overall net debt level equates to 0.80 times annualized, anticipated Q4 2012 cash flow or 0.55 times anticipated 2013 cash flows.2013 Capital BudgetA $650.0 million EP capital program is planned for 2013 - an increase from the earlier preliminary 2013 budget estimates of $575.0 million. $485.0 million is planned for drilling and completion activity in 2013, yielding an approximate total of 115 wells (100 horizontals, 15 verticals) throughout existing core EP areas. 2013 facilities and infrastructure spending of $115 million is anticipated, including completion of new facilities at Spirit River, Alberta and Doe, B.C.  Additional 2013 facilities projects include a 50 mmcfpd capacity expansion in the Alberta Deep Basin in 2H 2013 as well as two major gas pipeline laterals in the Deep Basin further expanding the extent of Tourmaline's gas processing and transportation network.The $650.0 million 2013 capital program compares to anticipated 2013 cash flows of $636.7 million, based on average 2013 production levels of 75,000 boepd and an assumed gas price of $3.86/mcf AECO and an average Edmonton par oil price of $90.00/bbl.Tourmaline has been seeking to divest its Elmworth/Wapiti Alberta Montney assets and anticipates consummating a transaction in the first quarter of 2013.  Proceeds from the potential disposition would be utilized for either additional acquisitions, a further 2013 EP capital program expansion or for balance sheet strengthening, depending upon the commodity price outlook at that time.EP Program OverviewTourmaline has embarked upon an accelerated growth plan for all three core areas through an expanded EP capital program and complementary acquisitions. The Company has accelerated and expanded its 2H 2012 EP program in response to additional available funds raised during the third quarter and an improving natural gas price environment.The operated-rig count was increased to eight rigs, with six rigs currently drilling in the Alberta Deep Basin, one rig operating at Spirit River and one rig operating in the NEBC Montney complex.Alberta Deep BasinThe Musreau gas plant expansion was completed in September, bringing operated production in the immediate area to 50 mmcfpd and total current Company production in the Deep Basin to approximately 230 mmcfpd. The Company has an additional 55 mmcfpd of production to bring on-stream from wells already completed, tested and shut-in.Tourmaline is currently operating six drilling rigs in the Deep Basin, five of which are pursuing horizontal targets in the Wilrich, Notikewin, and Falher formations. The Company has targeted 25 - 30 new Wilrich horizontals to be drilled, completed and on-stream between July 2012 and April 2013 via the ongoing EP program. The three most recent Wilrich horizontal wells at Minehead, Ansel and Sundance tested at final production rates of 24.5 mmcfpd @ 24.3 MPa, 23.4 mmcfpd @ 23.1 MPa, and 15.1 mmcfpd @ 14.6 MPa, respectively, on three-day tests.(1) All three will be tied in by year end 2012 or early in 2013.The Company has entered into an agreement to acquire all the assets of a private company in the Wild River area of the Alberta Deep Basin. The assets include approximately 3,000 boepd of existing production, a portion of which is already operated by Tourmaline, the remaining 30% joint interest in the Wild River gas plant, two drilled but uncompleted horizontal wells and a significant complementary land and development drilling inventory. The $84.1 million cash acquisition closed on November 7, 2012.NEBC MontneyCurrent production at Sunrise-Dawson is 70 - 75 mmcfpd through the existing Tourmaline infrastructure, with an additional 90 mmcfpd completed, tested and currently shut-in. The second Tourmaline gas plant at Doe, with a planned capacity of 50 mmcfpd, is scheduled for an early April 2013 completion. Start-up of this plant, along with closing of the previously announced Huron acquisition, is anticipated to bring Company interest NEBC production to approximately 30,000 boepd.Tourmaline is currently operating one drilling rig in NEBC, focussing on the highest liquid content gas targets within the vertically stacked series of Triassic Montney turbidite lobes. Condensate and NGL rates as high as 60 bbls/mm have been encountered in new turbidite lobes currently being delineated. Drilling and completion capital costs continue to trend downward; completed well costs averaged $3.55 million (drill, complete and stimulate) on the most recent Dawson four-well Montney pad.(1) Production tests are not necessarily indicative of long-term performance or ultimate recovery.Tourmaline is currently planning to employ a second drilling rig in NEBC to further delineate the Huron assets in 2013. These assets will provide Tourmaline with a significant increase in future liquid-rich Montney lands and horizontal drilling targets. Huron has also constructed significant complementary infrastructure in the adjoining Montney play areas that can be utilized to rapidly bring existing and new production volumes on-stream.Spirit RiverThe main emphasis of the 2H 2012 Spirit River drilling program is to delineate the significant Charlie Lake pool expansion potential. The Company now believes that the original Triassic Charlie Lake oil accumulation is substantially larger than originally estimated. Thus far in the second half of 2012, five new successful horizontals have been drilled in these peripheral areas East and South of the original pool. Three of these horizontals have been on production for 14 days or longer, with current oil rates of 174, 417 and 474 bpd, respectively, and total current hydrocarbon production rates of 432, 492 and 619 boepd, respectively, including associated gas production. The Company is planning to have a total of eight pool expansion delineation horizontals drilled, completed and producing by year end 2012. The future horizontal drilling inventory at Spirit River is now in excess of 200 locations, as the property grows into a stand-alone third core operating complex for the Company.Current production rates at Spirit River are constrained by limitations within the existing gas handling infrastructure. This has resulted in lower total Spirit River pool volumes than originally expected for the second half of 2012 and the first quarter of 2013. These constraints on both oil and total production rates are being addressed by a gas facility expansion that will increase gas handling capability from 16.0 to 40.0 mmcfpd, with an associated significant increase in oil and liquids production capability. This facility expansion was initiated in Q3 2012 and is expected to be completed in March 2013. Current production volumes at Spirit River are 5,500 - 6,000 boepd (2,700 - 3,000 bpd oil, 15 - 16 mmcfpd gas) with additional shut-in volumes at Spirit River estimated at 3,500 boepd. The Spirit River gas has a hydrocarbon liquid content of up to 102 bbls/mm providing an attractive secondary liquid target that the Company will pursue in 2013.       CORPORATE SUMMARY - THIRD QUARTER 2012              Three Months Ended September 30, Nine Months Ended September 30, 2012 2011 Change 20122011 ChangeOPERATIONS               Production                Natural gas (mcf/d) 255,451  185,414 38%  256,235  154,360 66% Crude oil and NGL (bbls/d) 5,600  3,444 63%  5,940  2,953 101% Oil equivalent (boe/d) 48,175  34,347 40%  48,646  28,680 70%                Product prices(1)                Natural gas ($/mcf)$2.52 $4.25 (41)% $ 2.42 $4.35 (44)% Crude oil and NGL ($/bbl)$83.34 $87.01 (4)% $ 83.87 $88.80 (6)%                Operating expenses ($/boe)$3.66 $5.77 (37)% $4.56 $ 5.76 (21)%                Transportation expenses ($/boe)$1.97 $2.06 (4)% $ 1.87 $ 1.99 (6)%                Operating netback ($/boe)$15.68 $21.21 (26)% $15.12 $22.77 (34)%                Cash general & administrativeexpenses($/boe)(2)$0.79 $0.94 (16)% $ 0.79 $1.10 (28)%                                Financial ($000, except per share)               Revenue  102,127   100,068 2%  306,726  255,048 20%Royalties 7,641  8,313 (8)%  19,511  16,043 22%                Funds from operations 63,515  62,686 1%  186,472  168,041 11%Funds from operations per share$0.38 $ 0.40 (5)% $1.13 $1.13 -%                Net earnings (loss) (4,770)  8,688 (155)%   (782)  26,607 (103)%Net earnings (loss) per share$(0.03) $0.06 (150)% $(0.00) $0.18 (100)%                Capital expenditures 175,277  249,162 (30)%  445,532  596,789 (25)%                Weighted average shares outstanding(diluted)         164,854,721  148,999,440 11%                Net debt          (311,847)  (283,704) 10%                                (1)  Product prices include realized gains and losses on financial instrument contracts.(2)  Excluding interest and financing charges.Forward-Looking InformationThis press release contains forward-looking information within the meaning of applicable securities laws. The use of any of the words "expect", "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 anticipated petroleum and natural gas production, cash flows, net debt levels, capital efficiency and capital spending, projected operating costs, acquisition and disposition initiatives, the timing for facility expansions, as well as Tourmaline's future drilling prospects and plans, 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 exchange rates; applicable royalty rates and tax laws; future well production rates and reserve volumes; the timing of receipt of regulatory approvals; the performance of existing wells; the success obtained in drilling new wells; the sufficiency of budgeted capital expenditures in carrying out planned activities; the successful completion of acquisition and dispositions; and the availability and cost of labour and services. Although Tourmaline believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Tourmaline can give no assurances that they 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, costs and expenses; health, safety and environmental risks; commodity price and exchange rate fluctuations; marketing and transportation; loss of markets; environmental risks; competition; incorrect assessment of the value of acquisitions; failure to complete or realize the anticipated benefits of acquisitions or dispositions; 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.Also included in this press release are estimates of Tourmaline's 2012 and 2013 cash flows, which are 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 - $2.43/mcf) (2012), $3.86/mcf (2013), and crude oil (WTI (US) - $94.65/bbl) (2012) and $95.00/bbl (2013) and an exchange rate assumption of $0.99 (US/CAD) for 2012 and $1.00 (US/CAD) for 2013. To the extent such estimate constitutes a financial outlook, it was approved by management and the Board of Directors of Tourmaline on November 7, 2012 and is included to provide readers with an understanding of Tourmaline's anticipated cash flow based on the capital expenditure and other assumptions described herein and readers are cautioned that the information may not be appropriate for other purposes.Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on these and other factors that could affect Tourmaline, or its operations or financial results, are included in the Management's Discussion and Analysis forming part of this press release (See "Forward-Looking Statements" therein) and reports on file with applicable securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com) or Tourmaline's website (www.tourmalineoil.com).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 laws.Additional Reader AdvisoriesSee also "Forward-Looking Statements", "Boe Conversions" and "Non-IFRS Financial Measures" in the attached Management's Discussion and Analysis."Funds from operations",  "operating netback" and "net debt" as used in this press release are financial measures commonly used in the oil and gas industry, which do not have any standardized meaning prescribed by International Financial Reporting Standards ("IFRS"). See "Non-IFRS Financial Measures" in the attached Management's Discussion and Analysis for the definition and description of these terms.Certain Definitions:bbls barrelsboe barrel of oil equivalentboepd barrel of oil equivalent per daybopd barrel of oil, condensate or liquids per daygjsd gigajoules per daymmboe millions of barrels of oil equivalentmbbls thousand barrelsmmcf million cubic feetmmcfpd million cubic feet per daymmcfpde million cubic feet per day equivalentmcfe thousand cubic feet equivalentmmbtu million British thermal units  Conference Call Tomorrow at 9:00 a.m. MT (11:00 a.m. ET)Tourmaline will host a conference call tomorrow, November 9, 2012 starting at 9:00 a.m. MT (11:00 a.m. ET). To participate, please dial 1-888-231-8191 (toll-free in North America), or local dial-in 647-427-7450, a few minutes prior to the conference call.The conference call ID number is 61077869.MANAGEMENT'S DISCUSSION AND ANALYSISThis management's discussion and analysis ("MD&A") should be read in conjunction with Tourmaline's unaudited interim condensed consolidated financial statements and related notes for the three and nine months ended September 30, 2012 and the consolidated financial statements for the year ended December 31, 2011.  Both the consolidated financial statements and the MD&A can be found at www.sedar.com.  This MD&A is dated November 7, 2012.The financial information contained herein has been prepared in accordance with International Financial Reporting Standards ("IFRS").  All dollar amounts are expressed in Canadian currency, unless otherwise noted.Certain financial measures referred to in this MD&A are not prescribed by IFRS. See "Non-IFRS Financial Measures" for information regarding the following Non-IFRS financial measures used in this MD&A: "funds from operations", "operating netback", "working capital (adjusted for the fair value of financial instruments)" and "net debt".Additional information relating to Tourmaline can be found at www.sedar.com.Forward-Looking Statements - Certain information regarding Tourmaline set forth in this document, including management's assessment of the Company's future plans and operations, contains forward-looking statements that involve substantial known and unknown risks and uncertainties. The use of any of the words "anticipate", "continue", "estimate", "expect", "may", "will", "project", "should", "believe" and similar expressions are intended to identify forward-looking statements. Such statements represent Tourmaline's internal projections, estimates or beliefs concerning, among other things, an outlook on the estimated amounts and timing of capital investment, anticipated future debt, production, revenues or other expectations, beliefs, plans, objectives, assumptions, intentions or statements about future events or performance. These statements are only predictions and actual events or results may differ materially. Although Tourmaline believes that the expectations reflected in the forward-looking statements are reasonable, it cannot guarantee future results, levels of activity, performance or achievement since such expectations are inherently subject to significant business, economic, competitive, political and social uncertainties and contingencies. Many factors could cause Tourmaline's actual results to differ materially from those expressed or implied in any forward-looking statements made by, or on behalf of, Tourmaline.In particular, forward-looking statements included in this MD&A include, but are not limited to, statements with respect to: the size of, and future net revenues from, crude oil, NGL (natural gas liquids) and natural gas reserves; future prospects; the focus of and timing of capital expenditures; expectations regarding the ability to raise capital and to continually add to reserves through acquisitions and development; access to debt and equity markets; projections of market prices and costs; the performance characteristics of the Company's crude oil, NGL and natural gas properties; crude oil, NGL and natural gas production levels and product mix; Tourmaline's future operating and financial results; capital investment programs; supply and demand for crude oil, NGL and natural gas; future royalty rates; drilling, development and completion plans and the results therefrom; future land expiries; dispositions and joint venture arrangements; amount of operating, transportation and general and administrative expenses; treatment under governmental regulatory regimes and tax laws; and estimated tax pool balances.  In addition, statements relating to "reserves" are deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves described can be profitably produced in the future.These forward-looking statements are subject to numerous risks and uncertainties, most of which are beyond the Company's control, including the impact of general economic conditions; volatility in market prices for crude oil, NGL and natural gas; industry conditions; currency fluctuation; imprecision of reserve estimates; liabilities inherent in crude oil and natural gas operations; environmental risks; incorrect assessments of the value of acquisitions and exploration and development programs; competition; the lack of availability of qualified personnel or management; changes in income tax laws or changes in tax laws and incentive programs relating to the oil and gas industry; hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; stock market volatility; ability to access sufficient capital from internal and external sources; the receipt of applicable approvals; and the other risks considered under "Risk Factors" in Tourmaline's most recent annual information form available at www.sedar.com.With respect to forward-looking statements contained in this MD&A, Tourmaline has made assumptions regarding: future commodity prices and royalty regimes; availability of skilled labour; timing and amount of capital expenditures; future exchange rates; the impact of increasing competition; conditions in general economic and financial markets; availability of drilling and related equipment and services; effects of regulation by governmental agencies; and future operating costs.Management has included the above summary of assumptions and risks related to forward-looking information provided in this MD&A in order to provide shareholders with a more complete perspective on Tourmaline's future operations and such information may not be appropriate for other purposes.  Tourmaline's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that the Company will derive therefrom.  Readers are cautioned that the foregoing lists of factors are not exhaustive.These forward-looking statements are made as of the date of this MD&A and the Company disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.Boe Conversions - Per barrel of oil equivalent amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil equivalent (6:1). Barrel of oil equivalents (Boe) 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.PRODUCTION               Three Months Ended  Nine Months Ended    September 30,2012 September 30,2011 Change September 30,2012 September 30,2011 ChangeNatural Gas (mcf/d) 255,451 185,414 38% 256,235 154,360 66%Crude oil and NGL (bbl/d) 5,600 3,444 63% 5,940 2,953 101%Oil equivalent (Boepd) 48,175 34,347 40% 48,646 28,680 70%             Production for the three months ended September 30, 2012, averaged 48,175 Boe/d, a 40% increase over the average production for the same quarter of 2011 of 34,347 Boe/d.  Production was 88% natural gas weighted in the third quarter of 2012 compared to 90% natural gas weighted in the third quarter of 2011.For the nine months ended September 30, 2012, production increased 70% to 48,646 Boe/d from 28,680 Boe/d for the same period of 2011.The Company's significant production growth when compared to 2011 can be attributed to new wells that have been brought on-stream since September 30, 2011, as well as property and corporate acquisitions.REVENUE                Three Months Ended  Nine Months Ended  (000s)  September 30,2012  September 30,2011  Change  September 30,2012  September 30,2011 ChangeRevenue from:                   Natural Gas $59,195 $72,494 (18)% $170,225 $183,458 (7)%   Oil and NGL  42,932  27,574 56%  136,501  71,590 91%Total revenue from gas, oil and NGL sales $102,127 $100,068 2% $306,726 $255,048 20%                 Revenue for the three months ended September 30, 2012 increased 2% to $102.1 million from $100.1 million for the same quarter of 2011. For the nine months ended September 30, 2012, revenue was $306.7 million, a 20% increase over revenue of $255.0 million for the same period of 2011.  Revenue growth is consistent with the increase in production over the same periods, partially offset by lower realized commodity prices.  Revenue includes all petroleum, natural gas and NGL sales and realized gains on financial instruments.Tourmaline Prices:        Three Months Ended   Nine Months Ended     September 30,2012  September 30,2011 Change  September 30,2012  September 30,2011 ChangeNatural Gas ($/mcf) $2.52 $4.25 (41)% $2.42 $4.35 (44)%Oil and NGL ($/bbl) $83.34 $87.01 (4)% $83.87 $88.80 (6)%Oil equivalent ($/Boe) $23.04 $31.67 (27)% $23.01 $32.57 (29)%                 The realized average natural gas prices for the three and nine months ended September 30, 2012 were 41% and 44%, respectively, lower than the same periods of the prior year.  Realized crude oil and NGL prices decreased 4% and 6% for the three and nine months ended September 30, 2012, respectively, compared to the same periods of 2011.The realized natural gas price for the quarter ended September 30, 2012 was $2.52/mcf, which is 10% (September 30, 2011 - 16%) higher than the AECO benchmark due to a combination of higher heat content in the Company's Alberta Deep Basin natural gas production and positive commodity contracts. Realized prices exclude the effect of unrealized gains or losses. Once these gains and losses are realized they are included in the per unit amounts.Benchmark Oil and Gas Prices:           Three Months Ended     September 30,2012  September 30,2011 ChangeNatural Gas         NYMEX Henry Hub (US$/mcf) $2.89 $4.06 (29)% AECO (CAD$/mcf) $2.30 $3.67 (37)%Oil         NYMEX (US$/bbl) $92.20 $89.54 3% Edmonton Par (CAD$/bbl) $84.87 $92.35 (8)%          Reconciliation of AECO Index to Tourmaline's Realized Gas Prices:           Three Months Ended  ($/mcf)  September 30,2012  September 30,2011 ChangeAECO index $2.30 $3.67 (37)%Heat/quality differential  0.18  0.24 (25)%Realized gain  0.04  0.34 (88)%Tourmaline realized natural gas price $2.52 $4.25 (41)%Currency - Exchange Rates:            Three Months Ended    September 30,2012 September 30,2011 ChangeCAD/US$ $1.0043 $1.0201 (2)%ROYALTIES  Three Months Ended Nine Months Ended(000s)  September 30,2012  September 30,2011  September 30,2012  September 30,2011Natural Gas $592 $3,270 $(1,509) $4,879Oil and NGL  7,049  5,043  21,020  11,164Total royalties $7,641 $8,313 $19,511 $16,043Royalties as a percentage of revenue  7.5%  8.3%  6.4%  6.3%             For the quarter ended September 30, 2012, the average effective royalty rate decreased to 7.5% compared to 8.3% for the same quarter of 2011.  For the nine months ended September 30, 2012, the average effective royalty was 6.4% compared to 6.3% for the same period of 2011.  The Company continues to benefit from the New Well Royalty Reduction Program and the Natural Gas Deep Drilling Program in Alberta as well as the Deep Royalty Credit Program in British Columbia.The Company expects its royalty rate for 2012 to remain unchanged at 7% as previously forecasted at June 30, 2012.  The royalty rate is sensitive to commodity prices, however, and as such, a change in commodity prices will impact the actual rate.OTHER INCOMEFor the quarter ended September 30, 2012, other income was $0.9 million, which includes $0.8 million in processing income, compared to $1.4 million for the same quarter of 2011, of which $1.3 million related to processing income. Processing income has been decreasing as a smaller amount of third-party production has been processed in Tourmaline owned-and-operated facilities as the Company grows the amount of its own production, thus reducing capacity for third-party volumes.  For the nine months ended September 30, 2012, other income was $3.7 million compared to $3.4 million for the same period of the prior year.OPERATING EXPENSES           Three Months Ended   Nine Months Ended  ($000s, except perunit amounts)  September 30,2012  September 30,2011 Change  September 30,2012  September 30,2011 ChangeOperating expenses $16,236 $18,239 (11)% $60,736 $45,101 35%Per Boe $3.66 $5.77 (37)% $4.56 $5.76 (21)%                 Operating expenses include all periodic lease and field-level expenses and exclude income recoveries from processing third-party volumes.  For the third quarter of 2012, total operating expenses decreased 11% from $18.2 million in the third quarter of 2011 to $16.2 million in 2012 due to the impact of redirecting natural gas from third-party facilities to Tourmaline owned-and-operated infrastructure.  On a per Boe basis, the costs decreased 37% from $5.77/Boe for the third quarter of 2011 to $3.66/Boe in the third quarter of 2012 due to increased production and increased operational efficiencies.  Tourmaline's operating expenses in the third quarter of 2012 include third-party processing, gathering and compression fees of approximately $4.3 million or 27% of total operating costs (September 30, 2011- $5.5 million or 30% of total operating costs).For the nine months ended September 30, 2012, total operating expenses were $60.7 million, or $4.56/Boe, compared to $45.1 million, or $5.76/Boe for the same period of 2011. Although total operating expenses increased commensurate with production, the costs per Boe decreased 21% reflecting increased operational efficiencies.The Company now expects its full year 2012 operating costs to average approximately $4.75 per Boe, which is a reduction from its previous guidance of $5.00 per Boe.  Actual costs per Boe can change, however, depending on a number of factors including the Company's actual production levels.TRANSPORTATIONTransportation costs for the three months ended September 30, 2012 were $8.7 million or $1.97 per Boe (three months ended September 30, 2011 - $6.5 million or $2.06 per Boe, respectively).  Transportation costs for the nine months ended September 30, 2012 were $24.9 million or $1.87 per Boe (nine months ended September 30, 2011 - $15.6 million or $1.99 per Boe, respectively).  On a per Boe basis, transportation costs for the three and nine months ended September 30, 2012 are lower primarily due to the expansion of the Company's owned-and-operated Sunrise plant in December 2011 whereby increased volumes are now going to this plant which is in closer proximity versus previous third-party facilities.  The increase in total transportation costs for the nine months ended September 30, 2012 can be attributed to increased production.GENERAL & ADMINISTRATIVE EXPENSES ("G&A")                   Three Months Ended   Nine Months Ended  (000s)  September 30,2012  September 30,2011 Change  September 30,2012  September 30,2011 ChangeG&A expenses $6,667 $6,082 10% $19,550 $17,587 11%Administrative and capital recovery  (484)  (939) (48)%  (822)  (2,527) (67)%Capitalized G&A  (2,685)  (2,167) 24%  (8,184)  (6,436) 27%Total G&A expenses $3,498 $2,976 18% $10,544 $8,624 22%Per Boe $0.79 $0.94 (16)% $0.79 $1.10 (28)%                 G&A expenses for the third quarter of 2012 were $3.5 million compared to $3.0 million for the same quarter of the prior year.  G&A costs per Boe for the third quarter of 2012 decreased 16% down to $0.79 per Boe, compared to $0.94 per Boe for the same quarter of 2011.For the nine months ended September 30, 2012, G&A expenses were $10.5 million or $0.79/Boe compared to $8.6 million or $1.10/Boe for the same period of 2011.  The increase in G&A expenses in 2012 compared to 2011 is primarily due to office staff additions and higher rent expense as the Company increased its head office space. The higher total G&A expenses result from the need to manage the larger production, reserve and land base.  Notwithstanding this, the Company's G&A expenses per Boe continue to trend downward as Tourmaline's production base continues to grow faster than its accompanying G&A costs.G&A costs for 2012 are not expected to exceed $1.00 per Boe.  Actual costs per Boe can change, however, depending on a number of factors including the Company's actual production levels.SHARE-BASED COMPENSATION    Three Months EndedNine Months Ended(000s) September 30,2012 September 30,2011 September 30,2012 September 30,2011Share-based payments    $    7,150    $    6,516    $22,182$17,104Capitalized share-based payments         (3,575)         (3,258)     (11,091) (8,552)Total share-based payments    $    3,575    $    3,258    $11,091$8,552Per Boe    $    0.81    $    1.03    $    0.83$1.09         Tourmaline uses the fair value method for the determination of non-cash related share-based payments expense. During the third quarter of 2012, 75,000 stock options were granted to employees, officers, directors and key consultants at a weighted-average exercise price of $28.92, and 579,291 options were exercised, bringing $6.6 million of cash into treasury. The Company recognized $3.6 million of share-based payment expense in the third quarter of 2012 compared to $3.3 million in the third quarter of 2011.  Capitalized share-based payment expense for the third quarter of 2012 was $3.6 million compared to $3.3 million for the same quarter of the prior year.For the nine months ended September 30, 2012, share-based expense totalled $11.1 million and capitalized share-based payments were $11.1 million (2011 - $8.6 million and $8.6 million, respectively).   The increase in share-based payment expense in 2012 compared to 2011 reflects the increased number of employees due to increased activity.DEPLETION, DEPRECIATION AND AMORTIZATION ("DD&A") Three Months EndedNine Months Ended($000s, except per unit amounts) September 30,2012 September 30,2011 September 30,2012 September 30,2011Depletion, depreciation and amortization    $    58,733    $    48,059    $176,530$    116,928Per Boe    $    13.25    $    15.21    $13.24$    14.93DD&A expense was $58.7 million for the third quarter of 2012 compared to $48.1 million for the same period of 2011 due to higher production volumes, as well as a larger capital asset base being depleted.  The per-unit DD&A rate for the third quarter of 2012 was $13.25/Boe compared to $15.21/Boe for the third quarter of 2011.For the nine months ended September 30, 2012, DD&A expense was $176.5 million (September 30, 2011 - $116.9 million) with an effective rate of $13.24/Boe (September 30, 2011 - $14.93/Boe).  The lower DD&A rate, for both the three and nine months ended September 30, 2012 compared to the same periods of 2011, reflects strong reserve additions derived from Tourmaline's exploration and production program.FINANCE EXPENSESFinance expenses for the three and nine months ended September 30, 2012 totalled $3.6 million and $8.5 million, respectively, and are comprised of interest expense and accretion of provisions (September 30, 2011 - $3.0 million and $5.1 million, respectively).  The increased finance expenses are largely due to higher interest expense resulting from a higher balance drawn on the credit facility in 2012.CASH FLOW FROM OPERATIONS, FUNDS FROM OPERATIONS AND NET EARNINGS            Three Months Ended Nine Months Ended  September 30,2012 September 30,2011Change September 30,2012 September 30,2011ChangeCash flow from operating activities $ 66,713    $77,622    (14)%   $168,806$166,6201%                           Funds from operations (2)   $63,515    $ 62,686    1%   $186,472$168,04111%Funds from operations per share (1) (2)   $ 0.38    $ 0.40    (5)%   $1.13$1.13-%                               Net earnings (loss)   $(4,770)    $ 8,688(155)%    $(782)$26,607(103)%Earnings (loss) per share (1)   $(0.03)    $0.06(150)%    $(0.00)$0.18(100)%                              Operating netback per Boe (2)  $15.68    $21.21    (26)%    $15.12$22.77(34)%(1) Fully diluted(2) See "Non-IFRS Financial Measures"                        Funds from operations for the three months ended September 30, 2012 were $63.5 million or $0.38 per diluted share compared to $62.7 million or $0.40 per diluted share for the same period of 2011.  For the nine months ended September 30, 2012, funds from operations were $186.5 million or $1.13 per diluted share, which is slightly higher than the September 30, 2011 funds from operations of $168.0 million or $1.13 per diluted share. Funds from operations in 2012 reflect lower natural gas prices over 2011 offset by increased production.The Company incurred an after-tax loss for both the three and nine months ended September 30, 2012 of $4.8 million ($0.03 per diluted share) and $0.8 million ($0.00 per diluted share), respectively, compared to earnings of $8.7 million ($0.06 per diluted share) and $26.6 million ($0.18 per diluted share), respectively, for the same periods of 2011.  The after-tax loss for the first nine months of 2012, compared to 2011, reflects significantly lower realized natural gas prices, a smaller unrealized gain on financial instruments as well as the recognition of the tax effect of the flow-through common shares as the costs are incurred.CAPITAL EXPENDITURES    Three Months EndedNine Months Ended(000s) September 30,2012 September 30,2011 September 30,2012 September 30,2011Land and seismic    $6,719    $10,508    $22,018$34,768Drilling and completions     116,721     119,574     289,506 285,391Facilities     43,333     51,081     131,489 168,413Property acquisitions     5,867     65,894     6,841 108,642Property dispositions     (65)     (357)     (12,633) (7,366)Other     2,702     2,462     8,311 6,941Total cash capital expenditures    $175,277    $249,162    $445,532$596,789During the third quarter of 2012, the Company invested $175.3 million of cash consideration, net of dispositions, compared to $249.2 million for the same period of 2011.  Expenditures on exploration and production were $166.8 million compared to $181.2 million for the same quarter of 2011. The lower expenditures in 2012 are a result of a reduced capital budget due to lower commodity prices realized in 2012.The following table summarizes the drill, complete and tie-in activities for the period:   Nine Months Ended    September 30, 2012       Gross  NetDrilled                 53  45.65Completed                 53  46.78Tied-in                 33  28.69LIQUIDITY AND CAPITAL RESOURCESOn April 4, 2012, the Company issued 1.4 million flow-through common shares at a price of $28.80 per share for total gross proceeds of $40.4 million. The proceeds were used to temporarily reduce bank debt and will be used to fund the Company's 2012 capital exploration program.On August 30, 2012, the Company issued 4.039 million common shares at a price of $29.00 per share for total gross proceeds of $117.1 million.  Subsequently, on September 19, 2012, the Underwriters exercised their over-allotment Option and purchased a further 0.6 million shares at a price of $29.00 per share for total gross proceeds of $17.4 million.  The proceeds were used to temporarily reduce indebtedness, which will then be available to be redrawn and applied to fund the expansion of the 2012 exploration and production capital program from $410 million to $525 million; to fund its 2013 capital expenditure program; and to fund general corporate expenditures.On October 9, 2012, the Company announced that it entered into a flow-through common share bought deal financing agreement.  The Company will issue 1,000,000 flow-through common shares at a price of $36.90 per share for gross proceeds of $36.9 million.  In addition, officers, directors and employees of Tourmaline will have the opportunity to purchase up to a maximum of 50,000 additional flow-through common shares at a price of $36.90 on a private placement basis.  The proceeds will be used to temporarily reduce bank debt.In June 2012, the Company amended and restated its bank credit facility to be a covenant-based facility rather than a borrowing base facility. This facility is a 3-year extendible revolving facility in the amount of $550 million plus a $25 million operating revolver from a syndicate of six lenders with an initial maturity date of June, 2015. The maturity date may, at the request of the Company and with the consent of the lenders, be extended on an annual basis. The facility is secured by a first ranking floating charge over all assets of the Company and its material subsidiaries.  The facility can be drawn in either Canadian or U.S. funds and bears interest at the bank's prime lending rate, bankers' acceptance rates or LIBOR (for U.S. borrowings), plus applicable margins.  The facility will provide the Company with greater flexibility by providing access to an additional $200 million over the previous facility.Under the terms of the bank credit facility, Tourmaline has provided its covenant that, on a rolling four quarter basis: (i) the ratio of EBITDA to interest expense shall equal or exceed 3.5:1, (ii) the ratio of senior debt to EBITDA shall not exceed 3:1, (iii) the ratio of total debt to EBITDA shall not exceed 4:1, and (iv) the ratio of senior debt to total capitalization shall not exceed 0.5:1.  As at September 30, 2012, the Company is in compliance with all debt covenants.At September 30, 2012, Tourmaline had negative working capital of $101.6 million, after adjusting for the fair value of financial instruments (the unadjusted working capital deficiency was $98.2 million) (December 31, 2011 - $146.6 million and $146.3 million, respectively).  Management believes the Company has sufficient liquidity and capital resources to fund the remainder of its 2012 and 2013 exploration and development program through expected cash flow from operations and its unutilized bank credit facility.  As at September 30, 2012, the Company's bank debt balance was $210.3 million (December 31, 2011 - $81.7 million), and net debt was $311.8 million (December 31, 2011 - $228.3 million).SHARES OUTSTANDINGAs at November 7, 2012, the Company has 166,971,178 common shares outstanding and 13,965,931 stock options granted and outstanding.COMMITMENTS AND CONTRACTUAL OBLIGATIONSIn the normal course of business, Tourmaline is obligated to make future payments.  These obligations represent contracts and other commitments that are known and non-cancellable.Payments Due by Year(000s) 2012 2013 2014 2015 2016 andThereafter TotalOperating leases$637$2,266$2,121$526$-$5,550Flow-through obligations     -     35,953     -     -     - 35,953Firm transportation agreements     7,246     29,693     21,609     12,171     1,058 71,777Bank debt(1)     -     -     -     235,382     - 235,382 $7,883$67,912$23,730$248,079$1,058$348,662(1) Includes interest expense at an annual rate of 3.55% being the rate applicable to outstanding bank debt at September 30, 2012.OFF BALANCE SHEET ARRANGEMENTSThe Company has certain lease arrangements, all of which are reflected in the commitments and contractual obligations table, which were entered into in the normal course of operations.  All leases have been treated as operating leases whereby the lease payments are included in operating expenses or general and administrative expenses depending on the nature of the lease.FINANCIAL RISK MANAGEMENTThe Board of Directors has overall responsibility for the establishment and oversight of the Company's risk management framework.  The Board has implemented and monitors compliance with risk management policies.The Company's risk management policies are established to identify and analyze the risks faced by the Company, to set appropriate risk limits and controls, and to monitor risks and adherence to market conditions and the Company's activities. The Company's financial risks are discussed in note 5 of the Company's audited consolidated financial statements for the year ended December 31, 2011.As at September 30, 2012, the Company has entered into certain financial derivative and physical delivery sales contracts in order to manage commodity risk.  These instruments are not used for trading or speculative purposes.  The Company has not designated its financial derivative contracts as effective accounting hedges, even though the Company considers all commodity contracts to be effective economic hedges.  Such financial derivative commodity contracts are recorded on the consolidated statement of financial position at fair value, with changes in the fair value being recognized as an unrealized gain or loss on the consolidated statement of income (loss) and comprehensive income (loss). The contracts that the Company has entered into in the first nine months of 2012 are detailed in note 3 of the Company's interim condensed consolidated financial statements for the three and nine months ended September 30, 2012.The following table provides a summary of the unrealized gains and losses on financial instruments for the three and nine months ended September 30, 2012: Three Months EndedNine Months Ended(000s) September 30,2012 September 30,2011 September 30,2012 September 30,2011Unrealized gain (loss) on financial instruments    $(3,551)    $5,139    $1,426$5,510Unrealized (loss) on investments held for trading     -     (64)     (103) (150)Total    $(3,551)    $    5,075    $1,323$5,360         The Company has entered into physical contracts to manage commodity risk.  These contracts are considered normal sales contracts and are not recorded at fair value in the consolidated financial statements.  These contracts have been disclosed in note 3 of the Company's interim condensed consolidated financial statements for the three and nine months ended September 30, 2012.SUBSEQUENT EVENTSOn October 9, 2012, the Company announced that it entered into a flow-through common share bought deal financing agreement.  The Company will issue 1,000,000 flow-through common shares at a price of $36.90 per share for gross proceeds of $36.9 million.  In addition, officers, directors and employees of Tourmaline will have the opportunity to purchase up to a maximum of 50,000 additional flow-through common shares at a price of $36.90 on a private placement basis.On October 23, 2012, Tourmaline entered in to an agreement with Huron Energy Corp. ("Huron"), a private corporation, pursuant to which Tourmaline will acquire all of the issued and outstanding shares of Huron on the basis of 0.07644 of a Tourmaline common share for each Huron common share. It is expected that Tourmaline will issue an aggregate of approximately 7.4 million common shares as part of the arrangement, which is expected to close on November 30, 2012.  The deal is subject to approval by the Huron shareholders.  It is estimated that the acquisition will add approximately 5,500 boepd of production.On November 7, 2012, Tourmaline closed an acquisition of a producing oil and gas asset, which is estimated to add approximately 3,000 boepd of production, for cash consideration of $84.1 million.APPLICATION OF CRITICAL ACCOUNTING ESTIMATESCertain accounting policies require that management make appropriate decisions with respect to the formulation of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses. Management reviews its estimates on a regular basis. The emergence of new information and changed circumstances may result in actual results or changes to estimates that differ materially from current estimates.  The Company's use of estimates and judgments in preparing the interim condensed consolidated financial statements is discussed in note 1 of the consolidated financial statements for the year ended December 31, 2011.DISCLOSURE CONTROLS AND PROCEDURES AND INTERNAL CONTROLS OVER FINANCIAL REPORTINGThe Company's Chief Executive Officer and Chief Financial Officer have designed, or caused to be designed under their supervision, disclosure controls and procedures ("DC&P") to provide reasonable assurance that: (i) material information relating to the Company is made known to the Company's Chief Executive Officer and Chief Financial Officer by others, particularly during the periods in which the annual and interim filings are being prepared; and (ii) information required to be disclosed by the Company in its annual filings, interim filings or other reports filed or submitted by it under securities legislation is recorded, processed, summarized and reported within the time period specified in securities legislation. All control systems by their nature have inherent limitations and, therefore, the Company's DC&P are believed to provide reasonable, but not absolute, assurance that the objectives of the control systems are met.The Company's Chief Executive Officer and Chief Financial Officer have designed, or caused to be designed under their supervision, internal controls over financial reporting ("ICFR") to provide reasonable assurance regarding the reliability of the Company's financial reporting and the preparation of financial statements for external purposes in accordance with IFRS. There were no changes in the Company's ICFR during the period beginning on June 30, 2012 and ending on September 30, 2012 that have materially affected, or are reasonably likely to materially affect, the Company's ICFR.It should be noted that a control system, including the Company's disclosure and internal controls and procedures, no matter how well conceived can provide only reasonable, but not absolute assurance that the objectives of the control system will be met and it should not be expected that the disclosure and internal controls and procedures will prevent all errors or fraud.BUSINESS RISKS AND UNCERTAINTIESTourmaline monitors and complies with current government regulations that affect its activities, although operations may be adversely affected by changes in government policy, regulations or taxation. In addition, Tourmaline maintains a level of liability, property and business interruption insurance which is believed to be adequate for Tourmaline's size and activities, but is unable to obtain insurance to cover all risks within the business or in amounts to cover all possible claims.See "Forward-Looking Statements" in this MD&A and "Risk Factors" in Tourmaline's most recent annual information form for additional information regarding the risks to which Tourmaline and its business and operations are subject.IMPACT OF NEW ENVIRONMENTAL REGULATIONSEnvironmental legislation, including the Kyoto Accord, the federal government's "EcoACTION" plan and Alberta's Bill 3 - Climate Change and Emissions Management Amendment Act, is evolving in a manner expected to result in stricter standards and enforcement, larger fines and liability and potentially increased capital expenditures and operating costs. Given the evolving nature of the debate related to climate change and the resulting requirements, it is not possible to determine the operational or financial impact of those requirements on Tourmaline.RECENT PRONOUNCEMENTS ISSUEDThe following pronouncements from the IASB will become effective for financial reporting periods beginning on or after January 1, 2013 and have not yet been adopted by the Company. All of these new or revised standards permit early adoption with transitional arrangements depending upon the date of initial application.       IFRS 9 - Financial Instruments addresses the classification and measurement of financial assets.       IFRS 10 - Consolidated Financial Statements builds on existing principles and standards and identifies the concept of control as the determining factor in whether an entity should be included within the consolidated financial statements of the parent company.       IFRS 11 - Joint Arrangements establishes the principles for financial reporting by entities when they have an interest in arrangements that are jointly controlled.       IFRS 12 - Disclosure of Interest in Other Entities provides the disclosure requirements for interests held in other entities including joint arrangements, associates, special purpose entities and other off balance sheet entities.       IFRS 13 - Fair Value Measurement defines fair value, requires disclosure about fair value measurements and provides a framework for measuring fair value when it is required or permitted within the IFRS standards.       IAS 19 - Employee Benefits revises the existing standard to eliminate options to defer the recognition of gains and losses in defined benefit plans, requires re-measurements of a defined benefit plan's assets and liabilities to be presented in other comprehensive income and increases disclosure.       IAS 27 - Separate Financial Statements revised the existing standard which addresses the presentation of parent company financial statements that are not consolidated financial statements.       IAS 28 - Investments in Associate and Joint Ventures revised the existing standard and prescribes the accounting for investments and sets out the requirements for the application of the equity method when accounting for investments in associates and joint ventures.    The Company has not completed its evaluation of the effect of adopting these standards on its financial statements.The IASB also issued Presentation of Items of Other Comprehensive Income, an amendment to IAS 1 Financial Statement Presentation. The amendment addresses the presentation of other comprehensive income and requires the grouping of items within other comprehensive income that might eventually be reclassified to the profit and loss section of the income statement. The change became effective on July 1, 2012.NON-IFRS FINANCIAL MEASURESThis MD&A includes references to financial measures commonly used in the oil and gas industry such as "funds from operations", "operating netback", "working capital (adjusted for the fair value of financial instruments)" and "net debt", which do not have any standardized meaning prescribed by IFRS.  Management believes that in addition to net income and cash flow from operating activities, the aforementioned 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, defines operating netback as revenue (excluding processing income) less royalties, transportation costs and operating expenses and defines working capital (adjusted for the fair value of financial instruments) as working capital adjusted for the fair value of financial instruments.  Net debt is defined as long-term bank debt plus working capital (adjusted for the fair value of financial instruments).Funds from OperationsA summary of the reconciliation of cash flow from operating activities (per the statement of cash flow), to funds from operations, is set forth below:          Three Months EndedNine Months Ended(000s) September 30,2012 September 30,2011 September 30,2012 September 30,2011Cash flow from operating activities    $66,713    $    77,622    $168,806    $166,620Change in non-cash working capital     (3,198)         (14,936)     17,666     1,421Funds from operations    $63,515    $    62,686    $186,472    $168,041         Operating NetbackOperating netback is calculated on a per-Boe basis and is defined as revenue (excluding processing income) less royalties, transportation costs and operating expenses, as shown below:    Three Months EndedNine Months Ended($/Boe) September 30,2012 September 30,2011    September 30,2012 September 30,2011Revenue, excluding processing income    $23.04    $    31.67    $23.01    $32.57Royalties         (1.72)         (2.63)     (1.46)     (2.05)Transportation costs         (1.97)         (2.06)     (1.87)     (1.99)Operating expenses         (3.66)         (5.77)     (4.56)     (5.76)Operating netback (1)    $    15.68    $    21.21    $15.12    $22.77(1)May not add due to rounding.Working Capital (Adjusted for the Fair Value of Financial Instruments)A summary of the reconciliation of working capital to working capital (adjusted for the fair value of financial instruments) is set forth below:     (000s) As atSeptember 30, 2012 As atDecember 31, 2011Working capital (deficit)    $(98,184)    $(146,317)Fair value of financial instruments - short-term (asset) liability     (3,393)     (276)Working capital (deficit) (adjusted for the fair value of financial instruments)    $(101,577)    $(146,593)Net DebtA summary of the reconciliation of net debt is set forth below:     (000s) As atSeptember 30, 2012 As atDecember 31, 2011Bank debt    $(210,270)    $(81,749)Working capital (deficit)     (98,184)     (146,317)Fair value of financial instruments - short-term (asset) liability     (3,393)     (276)Net debt    $(311,847)    $(228,342)SELECTED QUARTERLY INFORMATION              2012 2011 2010($000s, unless otherwise noted) Q3Q2Q1 Q4Q3Q2Q1 Q4PRODUCTION           Crude oil and NGL(bbls) 515,157596,992515,408 415,074316,890272,184217,121 236,502Gas (mcf) 23,501,48424,276,149 22,430,621 18,437,07917,058,132 13,798,65311,283,617 11,251,067Oil equivalent (Boe) 4,432,0714,643,0164,253,845 3,487,9203,159,912   2,571,9592,097,724 2,111,680Crude oil and NGL (bbls/d) 5,6006,5605,664 4,5123,4442,9912,412 2,571Gas (mcf/d) 255,451266,771246,490 200,403185,414151,634125,374 122,294Oil equivalent (Boe/d) 48,17551,02246,746 37,91234,34728,26323,308 22,953FINANCIAL            Gross revenue, net of royalties 91,863105,56794,781 98,30998,22587,55162,019 63,340Cash flow from operating activities 66,71342,56659,527 61,80177,62242,11246,886 46,109Funds from operations (1) 63,51561,12161,836 73,31162,68660,415            44,940 44,940 Per diluted share 0.380.370.38 0.450.400.410.32  0.34Net earnings (loss) (4,770)1,0122,976 16,0748,68815,1922,727 5,865 Per  basic share (0.03)0.010.02 0.100.060.110.02 0.05 Per diluted share (0.03)0.010.02 0.100.060.100.02 0.04Total assets  2,992,552 2,862,5022,878,261  2,711,024  2,517,607  2,030,285 1,936,836 1,816,043Working capital (98,184)(15,311)(176,029)  (146,317)  (120,080)  (31,963)(139,138) (49,642)Working capital (adjusted for the fairvalue of financial instruments) (1) (101,577)(19,809)(175,696)  (146,593)(123,858)  (31,592)(136,933) (49,170)Capital expenditures     175,27753,831216,424  232,167249,162 130,075 217,553 217,064Total outstanding shares (000s) 165,678160,459158,807 158,578151,906145,215138,124 136,191PER UNIT           Gas ($/mcf) 2.522.232.54 3.764.254.384.48 4.17Crude oil and NGL ($/bbl) 83.3477.75 91.48  93.05  87.0195.5483.00   75.94Revenue ($/Boe)  23.0421.6424.48 30.95  31.6733.6132.68  30.74Operating netback ($/Boe) (1)  15.6814.22 15.52 21.3921.2124.5222.99  22.66(1) See Non-IFRS Financial Measures.The oil and gas exploration and production industry is cyclical in nature. The Company's financial position, results of operations and cash flows are principally impacted by production levels, and commodity prices, particularly natural gas prices. The Company has had continued growth over the last eight quarters summarized in the table above.  The Company's average annual production has increased from 17,856 Boe per day in 2010 to 31,007 Boe per day in 2011, and 48,646 Boe per day in the first nine months of 2012.  The production growth can be attributed to both the Company's exploration and development activities, as well as from acquisitions of producing properties.  Over the same period, natural gas prices have declined, with the largest declines occurring in 2012.  The Company's cash flows from operating activities were $143.3 million in 2010, $228.4 million in 2011, and 2012 estimated cash flows (based on the first nine months annualized) are $225.1 million. The 2012 estimated cash flows reflect the effects of the lower realized natural gas prices in 2012.  Commodity price changes can indirectly impact expected production by changing the amount of funds available to reinvest in exploration, development and acquisition activities in the future.  Decreases in commodity prices not only reduce revenues and cash flows available for exploration, they may also challenge the economics of potential capital projects by reducing the quantities of reserves that are commercially recoverable.  The Company's capital program is dependent on cash flows generated from operations and access to capital markets.CONSOLIDATED FINANCIAL STATEMENTSCONSOLIDATED STATEMENTS OF FINANCIAL POSITION(000s) (unaudited)September 30, 2012December 31, 2011Assets  Current assets:     Accounts receivable$            47,747$            60,799 Prepaid expenses and deposits                 5,074                 5,313 Fair value of financial instruments (note 3)                 3,393                 276                  56,214                 66,388Investments                 -                 233Exploration and evaluation assets (note 4)                 639,590                 620,515Property, plant and equipment (note 5)                 2,296,748                 2,023,888 $            2,992,552$            2,711,024Liabilities and Shareholders' Equity                         Current liabilities:                          Accounts payable and accrued liabilities$            154,398$            212,705                  154,398                 212,705Bank debt (note 7)                 210,270                 81,749Decommissioning obligations (note 6)                 55,039                 50,463Long-term obligation                 8,070                 10,864Fair value of financial instruments (note 3)                 1,765                 74Deferred premium on flow-through shares                 7,576                 11,316Deferred taxes                 125,643                 107,977Shareholders' equity:                          Share capital (note 9)                 2,316,436                 2,140,660 Non-controlling interest (note 8)                 16,021                 15,079 Contributed surplus                 65,755                 47,776 Retained earnings                 31,579                 32,361                  2,429,791                 2,235,876 $            2,992,552$            2,711,024Commitments (note 12)Subsequent events (notes 3 and 13)See accompanying notes to the interim condensed consolidated financial statements. CONSOLIDATED STATEMENTS OF INCOME (LOSS) AND COMPREHENSIVE INCOME (LOSS) Three Months EndedNine Months Ended(000s) except per-share amounts (unaudited)September 30,2012September 30,2011September 30,2012September 30,2011Revenue:         Oil and natural gas sales$                99,817$            94,299$            294,914$            241,285 Royalties                     (7,641)                     (8,313)                 (19,511)                 (16,043)                      92,176                     85,986                 275,403                 225,242 Realized gain on financial instruments                     2,310                     5,769                 11,812                 13,763 Unrealized gain (loss) on financial instruments (note 3)           (3,551)           5,075                 1,323                 5,360 Other income                     928                     1,395                 3,673                 3,430                  91,863                       98,225                 292,211                 247,795Expenses:                                 Operating             16,236             18,239             60,736                 45,101 Transportation                     8,737                     6,503                 24,896                 15,586 General and administration                     3,498                     2,976                 10,544                 8,624 Share-based payments             3,575             3,258             11,091                 8,552 (Gain) loss on divestitures             (324)             -             (7,596)                 3,630 Depletion, depreciation and amortization                     58,733                     48,059                 176,530                 116,928                      90,455                     79,035                 276,201                 198,421Results from Operating Activities                     1,408                     19,190                 16,010                 49,374Finance expenses                     3,596                     3,048                 8,532                 5,081Income (loss) before taxes                     (2,188)                     16,142                 7,478                 44,293Deferred taxes                     2,363                     7,275                 7,318                 17,061Net income (loss) and comprehensive income(loss) for the period before non-controlling interest                     (4,551)                     8,867                 160                 27,232Net income (loss) and comprehensive income(loss) attributable to:                                 Shareholders of the Company                     (4,770)                     8,688                  (782)                 26,607 Non-controlling interest (note 8)                     219                     179                 942                 625 $                (4,551)$                8,867$            160$            27,232         Net income (loss) per share attributableto common shareholders (note 10)                                 Basic$                (0.03)    $            0.06$                (0.00)$            0.19 Diluted$                (0.03)$            0.06$                (0.00)$            0.18See accompanying notes to the interim condensed consolidated financial statements.CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY(000s) except per-share amounts (unaudited)          ShareCapital ContributedSurplus RetainedEarnings Non-ControllingInterest  Total EquityBalance at December 31, 2011$            2,140,660$            47,776$            32,361$15,079$      2,235,876Issue of common shares (note 9)             166,398             -             - - 166,398Share issue costs, net of tax             (5,701)                 -             -             -             (5,701)Share-based payments             -                 11,091             -             -             11,091Capitalized share-based payments     -                 11,091 -             -             11,091Options exercised (note 9)    -            15,079                 (4,203)             -             -             10,876Loss attributable to common shareholders                 -                 -             (782)       -             (782)Income attributable to non-controlling interest                 -                 -             - 942 942Balance at September 30, 2012$            2,316,436$            65,755$            31,579$16,021$            2,429,791(000s) except per-share amounts (unaudited)          ShareCapital ContributedSurplus RetainedEarnings (Deficit) Non-ControllingInterest Total EquityBalance at December 31, 2010$    1,508,052$        29,262$    (10,320)$13,909$        1,540,903Issue of common shares              423,819                -             -             -             423,819Share issue costs, net of tax              (7,994)                 -             -             -             (7,994)Share-based payments                -                 8,552             -             -             8,552Capitalized share-based payments                 -                 8,552             -             -             8,552Options exercised             13,056            (3,649)             -             -             9,407Income attributable to commonshareholders                 -                 -        26,607       -             26,607Income attributable to non-controlling interest                 -                 -             - 625             625Balance at September 30, 2011    $     1,936,933    $         42,717$         16,287$14,534$        2,010,471See accompanying notes to the interim condensed consolidated financial statements.CONSOLIDATED STATEMENTS OF CASH FLOW    Three Months EndedNine Months Ended(000s) (unaudited)September 30,2012September 30,2011September 30,2012September 30,2011Cash provided by (used in):        Operations:         Net income (loss)$  (4,770)$   8,688$ (782)$     26,607 Items not involving cash:                                 Depletion and depreciation               58,733           48,059         176,530                116,928  Accretion             325             335       940                1,009  Share-based payments            3,575            3,258          11,091             8,552  Deferred taxes          2,363               7,275         7,318              17,061  Unrealized (gain) loss on financial instruments(note 3)           3,551              (5,075)           (1,323)          (5,360)  Realized (gain) on sale of investments                      -            -         (38)             -  (Gain) loss on divestitures             (324)                    -        (7,596)           3,630  Non-controlling interest              219               179          942             625Decommissioning expenditures               (157)             (33)           (610)         (1,011)Changes in non-cash operating working capital             3,198            14,936       (17,666)             (1,421)           66,713             77,622       168,806           166,620Financing:                        Issue of common shares     141,170             3,862        185,783           230,846 Share issue costs             (5,457)                     (529)         (7,602)            (10,583) Increase (decrease) in bank debt          (104,788)             95,705      128,521            140,150              30,925             99,038        306,702           360,413Investing:                               Exploration and evaluation           (25,890)              (56,396)      (59,921)        (164,324) Property, plant and equipment            (143,585)              (127,229)           (391,403)           (331,189) Property acquisitions               (5,867)                (65,894)          (6,841)            (108,642) Proceeds from divestitures               65             357          12,633             7,366 Proceeds from sale of investments                -              -          168          338 Repayment of long-term obligation              (931)             (931)         (2,794)          (2,794) Changes in non-cash investing working capital            78,570           73,433       (27,350)           7,052              (97,638)          (176,660)           (475,508)          (592,193)Changes in cash                -                     -        -           (65,160)Cash, beginning of period          -            -      -      65,160Cash, end of period$       -$            -$     -$           -Cash is defined as cash and cash equivalents.See accompanying notes to the interim condensed consolidated financial statements.NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFor the three and nine months ended September 30, 2012 and 2011(tabular amounts in thousands of dollars, unless otherwise noted) (unaudited)Incorporation:Tourmaline Oil Corp. (the "Company") was incorporated under the laws of the Province of Alberta on July 21, 2008.  The Company is engaged in the acquisition, exploration, development and production of petroleum and natural gas properties.  These consolidated financial statements reflect only the Company's proportionate interest in such activities.The Company's registered office is located at 3700, 250 - 6th Avenue S.W., Calgary, Alberta, Canada T2P 3H7.1.   BASIS OF PREPARATIONThese unaudited interim condensed consolidated financial statements have been prepared in accordance with International Accounting Standard ("IAS") 34, "Interim Financial Reporting".  These unaudited interim condensed consolidated financial statements do not include all of the information and disclosure required in the annual financial statements and should be read in conjunction with the Company's audited consolidated financial statements for the year ended December 31, 2011.The accounting policies and significant accounting judgments, estimates, and assumptions used in these unaudited interim condensed consolidated financial statements are consistent with those described in Notes 1 and 2 of the Company's audited consolidated financial statements for the year ended December 31, 2011.The unaudited interim condensed consolidated financial statements were authorized for issue by the Board of Directors on November 7, 2012.2.   DETERMINATION OF FAIR VALUEA number of the Company's accounting policies and disclosures require the determination of fair value, for both financial and non-financial assets and liabilities. Fair values have been determined for measurement purposes based on the following method. When applicable, further information about the assumptions made in determining fair values is disclosed in the notes specific to that asset or liability.Measurement:Tourmaline classifies the fair value of transactions according to the following hierarchy based on the amount of observable inputs used to value the instrument.Level 1 - Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions occur in sufficient frequency and volume to provide pricing information on an ongoing basis.Level 2 - Pricing inputs are other than quoted prices in active markets included in Level 1. Prices are either directly or indirectly observable as of the reporting date. Level 2 valuations are based on inputs, including quoted forward prices for commodities, time value and volatility factors, which can be substantially observed or corroborated in the marketplace.Level 3 - Valuations in this level are those with inputs for the asset or liability that are not based on observable market data.3.   FINANCIAL RISK MANAGEMENTThe Board of Directors has overall responsibility for the establishment and oversight of the Company's risk management framework.  The Board has implemented and monitors compliance with risk management policies.The Company's risk management policies are established to identify and analyze the risks faced by the Company, to set appropriate risk limits and controls, and to monitor risks and adherence to market conditions and the Company's activities.  The Company's financial risks are consistent with those discussed in note 5 of the Company's audited consolidated financial statements for the year ended December 31, 2011.As at September 30, 2012, the Company has entered into certain financial derivative and physical delivery sales contracts in order to manage commodity risk.  These instruments are not used for trading or speculative purposes.  The Company has not designated its financial derivative contracts as effective accounting hedges, even though the Company considers all commodity contracts to be effective economic hedges.  As a result, all such commodity contracts are recorded on the interim condensed consolidated statement of financial position at fair value, with changes in the fair value being recognized as an unrealized gain or loss on the interim condensed consolidated statement of income (loss) and comprehensive income (loss).The Company has entered into the following financial derivative contracts since December 31, 2011 to September 30, 2012:         Financial Swaps:        Type of Contract Quantity Time Period Contract Price Fair ValueFinancial Swap 100 bbls/d July 2012 - June 2013 USD$100.10/bbl 176Financial Swap 100 bbls/d August 2012 - July 2013 USD$101.10/bbl 225Financial Swap 100 bbls/d August 2012 - December 2013 USD$100.60/bbl 318Financial Swap 100 bbls/d January 2013 - December 2013 USD$101.05/bbl 263Financial Swap 100 bbls/d July 2012 - March 2013 USD$103.30/bbl 180Financial Swap 100 bbls/d January 2013 - December 2013 USD$101.45/bbl 277Financial Swap 100 bbls/d January 2013 - December 2013 USD$103.40/bbl 347Financial Swap 100 bbls/d January 2013 - December 2013 USD$99.35/bbl 202       Financial Swaps/Swaptions:      Type of Contract Quantity Time Period Contract Price Fair ValueFinancial Swap(1) 400 bbls/d April 2012 - December 2012 USD$109.00/bbl 588Swaption(1) 400 bbls/d January 2013 - December 2013 USD$108.00/bbl (150)Financial Swap(2) 100 bbls/d July 2013 - December 2013 USD$99.00/bbl 100Swaption(2) 100 bbls/d January 2014 - December 2014 USD$100.00/bbl (225)Financial Swap(2) 100 bbls/d July 2013 - December 2013 USD$97.50/bbl 136Swaption(2) 100 bbls/d January 2014 - December 2014 USD$100.00/bbl (225)Financial Swap(2) 100 bbls/d July 2013 - December 2013 USD$103.75/bbl 185Swaption(2) 100 bbls/d January 2014 - December 2014 USD$100.00/bbl (225)Financial Swap(2) 100 bbls/d January 2013 - December 2013 USD$103.00/bbl 333Swaption(2) 100 bbls/d January 2014 - December 2014 USD$100.00/bbl (225)Financial Swap(3) 10,000 MMbtu/d January 2013 - December 2013 USD$4.15/MMbtu 1,095Swaption(3) 10,000 Mmbtu/d January 2014 - December 2014 USD$4.15/MMbtu (1,590)(1) This is a combined transaction (European swaption) whereby the Company provided the option to extend an oil swap into 2013 to realize a higher price on an oil swap in 2012.  The option to extend can only be exercised on December 31, 2012.(2) This is a combined transaction (European swaption) whereby the Company provided the option to extend an oil swap into 2014 to realize a higher price on an oil swap in 2013.  The option to extend can only be exercised on December 31, 2013.(3) This is a combined transaction (European swaption) whereby the Company provided the option to extend a gas swap into 2014 to realize a higher price on a gas swap in 2013.  The option to extend can only be exercised on December 23, 2013.No financial derivative contracts were entered into subsequent to September 30, 2012.As at September 30, 2012, if the future strip prices for oil were $1.00 per bbl higher and prices for natural gas were $0.10 per mcf higher, with all other variables held constant, before-tax earnings would have been $1.5 million (September 30, 2011 - $0.3 million) lower.  An equal and opposite impact would have occurred to before-tax earnings and the fair value of the derivative contracts liability if oil prices were $1.00 per bbl lower and gas prices were $0.10 per mcf lower.  In addition to the financial commodity contracts discussed above, the Company has entered into physical contracts to manage commodity risk. These contracts are considered normal sales contracts and are not recorded at fair value in the consolidated financial statements.On May 29, 2012, the Company entered into an interest rate swap. The following table outlines the realized and unrealized losses on the interest rate contract recorded on the consolidated statement of income (loss) and comprehensive income (loss) for the three and nine months ended September 30, 2012:(000s)               TermType(Floatingto Fixed) Amount CompanyFixed InterestRate (%) Counter PartyFloating RateIndex Three Months EndedSeptember 30, 2012 Nine Months EndedSeptember 30, 2012 Realized(Loss) UnrealizedGain Realized(Loss) Unrealized(Loss)May 29, 2012-May 29, 2014Swap $150,000 1.35% Floating Rate (49) 240 (65) (367)                The following table provides a summary of the unrealized gains (losses) on financial instruments for the three and nine months ended September 30, 2012 and 2011:    Three Months EndedNine Months Ended(000s) September 30,2012 September 30,2011 September 30,2012 September 30,2011Unrealized gain (loss) on financialinstruments    $            (3,551)     $            5,139    $            1,426$            5,510Unrealized (loss) on investments heldfor trading                 -                 (64)                 (103)             (150)Total    $            (3,551)    $            5,075    $            1,323$            5,360         The Company has entered into the following physical contracts since December 31, 2011 to September 30, 2012:          Type of Contract  Quantity  Time Period  Contract PriceAECO/Nymex Differential Swap  6,000 MMbtu/d(1)  February 2012 - December 2012  Nymex less USD$0.42/MMbtuAECO/Nymex Differential Swap  5,000 MMbtu/d  February 2012 - December 2012  Nymex less USD$0.325/MMbtuAECO/Nymex Differential Swap  7,000 MMbtu/d  February 2012 - December 2012  Nymex less USD$0.44/MMbtuAECO/Nymex Differential Swap  5,000 MMbtu/d  November 2012 - March 2013  Nymex less USD$0.405/MMbtuAECO/Nymex Differential Swap  5,000 MMbtu/d  November 2012 - October 2013  Nymex less USD$0.445/MMbtuAECO/Nymex Differential Swap  10,000 MMbtu/d  November 2012 - October 2013  Nymex less USD$0.3975/MMbtuAECO Costless Collar  5,000 Gjs/d  July 2012 - December 2012  $1.70/GJ floor - $2.15/GJ ceilingAECO Costless Collar  5,000 Gjs/d  July 2012 - December 2012  $1.80/GJ floor - $2.25/GJ ceilingAECO/Nymex Differential Swap  5,000 MMbtu/d  November 2012 - December 2013  Nymex less USD$0.425/MMbtuAECO/Nymex Differential Swap  10,000 MMbtu/d  January 2013 - December 2013  Nymex less USD$0.4575/MMbtuAECO/Nymex Differential Swap  10,000 MMbtu/d  January 2014 - December 2014  Nymex less USD$0.415/MMbtuAECO Fixed Price(2)  10,000 Gjs/d  January 2013 - December 2013  CAD$3.625/GJAECO Fixed Price Swaption(2)  15,000 Gjs/d  January 2014 - December 2014  CAD$3.50/Gj(1)This is a restructuring of a previously held contract whereby the volumes, contract price and time period of the contract were amended subsequent to December 31, 2011.(2)This is a combined transaction (European swaption) whereby the Company provided the option to extend a gas swap into 2014 to realize a higher price on a gas swap in 2013.  The option to extend can only be exercised on December 31, 2013. The following physical contracts were entered into subsequent to September 30, 2012:          Type of Contract  Quantity  Time Period  Contract PriceAECO Fixed Price(1)  10,000 Gjs/d  January 2013 - December 2013  CAD$3.64/GjAECO Fixed Price Swaption(1)  10,000 Gjs/d  January 2014 - December 2014  CAD$3.50/GjAECO Fixed Price(2)  10,000 Gjs/d  April 2013 - October 2013  CAD$3.65/GjAECO Fixed Price Swaption(2)  10,000 Gjs/d  November 2013 - October 2014  CAD$3.80/GjAECO/Nymex Differential Swap  10,000 MMbtu/d  November 2012 - March 2013  Nymex less USD$0.355/MMbtuAECO/Nymex Differential Swap  10,000 MMbtu/d  January 2013 - December 2013  Nymex less USD$0.435/MMbtu(1)This is a combined transaction (European swaption) whereby the Company provided the option to extend a gas swap into 2014 to realize a higher price on a gas swap in 2013.   The option to extend can only be exercised on December 31, 2013.(2)This is a combined transaction (European swaption) whereby the Company provided the option to extend a gas swap into 2014 to realize a higher price on a gas swap in 2013.   The option to extend can only be exercised on October 31, 2013. 4.   EXPLORATION AND EVALUATION ASSETS(000s)  As at December 31, 2011     $            620,515 Capital expenditures                  64,440 Transfers to property, plant and equipment (note 5)                 (47,174) Acquisitions                  7,538 Divestitures                  (5,729)As at September 30, 2012    $            639,590    General and administrative expenditures for the nine months ended September 30, 2012 of $3.9 million (December 31, 2011 — $8.2 million) have been capitalized and included as exploration and evaluation assets.  Non-cash share-based payment expense in the amount of $4.5 million (December 31, 2011 - $9.4 million) were also capitalized and included in exploration and evaluation assets.5.   PROPERTY, PLANT AND EQUIPMENTCost(000s)   As at December 31, 2011  $            2,276,303 Capital expenditures               397,975 Transfers from exploration and evaluation (note 4)               47,174 Change in decommissioning liabilities (note 6)               4,390 Acquisitions               4,103 Divestitures               (4,252)As at September 30, 2012  $            2,725,693Accumulated Depletion, Depreciation and Amortization(000s)  As at December 31, 2011 $            252,415 Depletion, depreciation and amortization              176,530As at September 30, 2012 $            428,945Net Book Value(000s)     As at December 31, 2011    $2,023,888As at September 30, 2012    $2,296,748General and administrative expenditures for the nine months ended September 30, 2012 of $4.3 million (December 31, 2011 - $1.8 million) have been capitalized and included as costs of oil and natural gas properties.  Also included in oil and natural gas properties is non-cash share-based payment expense of $6.6 million (December 31, 2011 - $2.3 million).Future development costs for the nine months ended September 30, 2012 of $1,674 million (December 31, 2011 - $1,539 million) were included in the depletion calculation.6.   DECOMMISSIONING OBLIGATIONSThe Company's decommissioning obligations result from net ownership interests in petroleum and natural gas assets including well sites, gathering systems and processing facilities.  The Company estimates the total undiscounted amount of cash flow required to settle its decommissioning obligations is approximately $76.7 million (December 31, 2011 - $72.5 million), with some abandonments expected to commence in 2021.    A risk-free rate of 2.49% (December 31, 2011 - 2.49%) and an inflation rate of 2.0% (December 31, 2011 - 2.0%) were used to calculate the fair value of the decommissioning obligations.(000s)Nine Months EndedSeptember 30, 2012 Year EndedDecember 31, 2011Balance, beginning of period    $            50,463 $            35,279 Obligation incurred                 4,198              6,048 Obligation incurred on corporate acquisitions                 -              2,430 Obligation incurred on property acquisitions                 192              1,845 Obligation divested                 (144)              (481) Obligation settled                 (610)              (1,047) Accretion expense                 940              1,315 Change in future estimated cash outlays                 -              5,074Balance, end of period    $55,039 $50,463      7.   BANK DEBTIn June 2012, the Company amended and restated its bank credit facility to a covenant-based facility rather than a borrowing base facility.  This facility is a three-year extendible revolving facility in the amount of $550 million plus a $25 million operating revolver from a syndicate of lenders with an initial maturity date of June 2015.  The maturity date may, at the request of the Company and with the consent of the lenders, be extended on an annual basis.  The facility is secured by a first ranking floating charge over all assets of the Company and its material subsidiaries.  The facility can be drawn in either Canadian or U.S. funds and bears interest at the bank's prime lending rate, bankers' acceptance rates or LIBOR (for U.S. borrowings), plus applicable margins, which range from 2.00 to 3.25 percent over bankers' acceptance rates depending on the Company's senior debt to EBITDA ratio.Under the terms of the bank credit facility, Tourmaline has provided its covenant that, on a rolling four quarter basis: (i) the ratio of EBITDA to interest expense shall equal or exceed 3.5:1, (ii) the ratio of senior debt to EBITDA shall not exceed 3:1, (iii) the ratio of total debt to EBITDA shall not exceed 4:1, and (iv) the ratio of senior debt to total capitalization shall not exceed 0.5:1.  As at September 30, 2012, the Company is in compliance with all debt covenants.As at September 30, 2012, Tourmaline's bank debt balance was $210.3 million (December 31, 2011 - $81.7 million).  In addition, Tourmaline has outstanding letters of credit of $3.5 million (December 31, 2011 - $3.6 million), which reduce the credit available on the facility.8.   NON-CONTROLLING INTERESTTourmaline owns 90.6 percent of Exshaw Oil Corp., a private company engaged in oil and gas exploration in Canada.A reconciliation of the non-controlling interest is provided below:(000s)   Nine Months EndedSeptember 30, 2012   Year EndedDecember 31, 2011Balance, beginning of period   $15,079   $13,909 Share of subsidiary's net income for the period    942    1,170Balance, end of period   $16,021   $15,0799.   SHARE CAPITAL(a)   AuthorizedUnlimited number of Common Shares without par value.Unlimited number of non-voting Preferred Shares, issuable in series.(b)   Common Shares Issued        Nine Months EndedSeptember 30, 2012  Year EndedDecember 31, 2011($000s) Number of Shares  Amount  Number of Shares  AmountBalance, beginning of period 158,577,586 $ 2,140,660  136,191,061 $      1,508,052For cash on public offering of common shares(3) 4,639,000     134,531  11,725,000              335,737For cash on public offering of flow-through common shares(1) (2) 1,402,000  31,867  1,361,500  44,290For cash on private placement of flow-through common shares -         -  1,580,000           39,658Issued on corporate acquisitions -        -  6,363,523        210,124For cash on exercise of stock options 1,058,992   10,876  1,356,502              12,532Contributed surplus on exercise of stock options -     4,203  -              4,856Share issue costs -    (7,602)  -    (19,329)Tax effect of share issue costs -              1,901  -              4,740Balance, end of period 165,677,578 $2,316,436  158,577,586 $    2,140,660(1) On December 1, 2011, the Company issued 1.36 million flow-through common shares at $41.00 per share for total gross proceeds of $55.8 million.  The implied premium on the flow-through common shares was determined to be $11.5 million or $8.47 per share.  A total of 0.16 million shares were purchased by insiders.  As at September 30, 2012, the Company had spent the full committed amount. The expenditures were renounced to investors in February 2012, with an effective date of renunciation of December 31, 2011.(2) On April 4, 2012, the Company issued 1.4 million flow-through common shares at $28.80 per share for total gross proceeds of $40.4 million.  The implied premium on the flow-through common shares was determined to be $8.5 million or $6.07 per share.  A total of 0.15 million shares were purchased by insiders.  As at September 30, 2012, the Company has spent $4.4 million on eligible expenditures and is committed to spend the remainder of $36.0 million on qualified exploration and development expenditures by December 31, 2013.  The expenditures will be renounced to investors with an effective renunciation date of December 31, 2012.(3)On August 30, 2012, the Company issued 4.039 million common shares at a price of $29.00 per share for total gross proceeds of $117.1 million.  A total of 39,000 shares were purchased by insiders.  Subsequently, on September 19, 2012, the Underwriters exercised their over-allotment Option and purchased a further 0.6 million shares at a price of $29.00 per share for total gross proceeds of $17.4 million.    10.   EARNINGS PER SHAREBasic earnings-per-share was calculated as follows:    Three Months EndedNine Months Ended  September 30,2012 September 30,2011 September 30,2012 September 30,2011Net earnings (loss) for the period (000s)    $(4,770)    $8,688    $(782)$26,607Weighted average number of common shares - basic                 162,032,270     151,044,426                 160,301,308 143,230,945Earnings (loss) per share - basic    $(0.03)    $0.06    $(0.00)$0.19         Diluted earnings-per-share was calculated as follows: Three Months EndedNine Months Ended  September 30,2012 September 30,2011 September 30,2012 September 30,2011Net earnings (loss) for the period(000s)    $(4,770)    $8,688    $(782)$26,607Weighted average number ofcommon shares - diluted(1)                 162,032,270     157,562,227                 160,301,308 148,999,440Earnings (loss) per share - fullydiluted    $(0.03)    $0.06    $(0.00)$0.18(1) The diluted weighted average number of common shares for the three and nine months ended September 30, 2012 are the same as that reported for basic weighted average number of common shares as they are anti-dilutive in determining earnings-per-share.There were 14,134,531 options excluded from the weighted-average share calculation for the nine months ended September 30, 2012 because they were anti-dilutive (September 30, 2011 - 1,640,000).11.   SHARE-BASED PAYMENTSThe Company has a rolling stock option plan.  Under the employee stock option plan, the Company may grant options to its employees up to 16,567,758 shares of common stock.  The exercise price of each option equals the volume-weighted average market price for the five days preceding the issue date of the Company's stock on the date of grant and the option's maximum term is five years.  Options are granted throughout the year and vest 1/3 on each of the first, second and third anniversaries from the date of grant.   Nine Months Ended September 30, 2012September 30, 2011  Number ofOptions WeightedAverageExercise Price Number ofOptions WeightedAverageExercise PriceStock options outstanding, beginning of period 14,213,523$16.82 11,997,000$12.24 Granted 980,000 23.57 1,730,000 28.74 Exercised (1,058,992) 10.27 (946,502) 9.94 Forfeited - - (179,999) 13.64Stock options outstanding, end of period 14,134,531$17.78 12,600,499$14.66The following table summarizes stock options outstanding and exercisable at September 30, 2012:             Range ofExercise Price NumberOutstandingat Period End WeightedAverageRemainingContractual Life  WeightedAverageExercisePrice NumberExercisable atPeriod End  WeightedAverageExercisePrice$7.00 - $8.00  2,445,051 1.15 $7.09 2,445,051 $7.09$10.00 - $15.00  4,349,790 1.96  12.86 3,463,123  12.31$16.68 - $32.78  7,339,690 3.67  24.25 2,179,333  21.00   14,134,531 2.68 $17.78 8,087,507 $13.07The fair value of options, granted during the year, was estimated on the date of grant using the Black-Scholes option-pricing model with the following weighted average assumptions and resulting values:          September 30,2012  September 30,2011Fair value of options granted (weighted average) $8.11 $10.92Risk-free interest rate  2.38%  2.12%Estimated hold period prior to exercise  4 years  5 yearsExpected volatility  40%  40%Forfeiture rate  2%  2%Dividend per share $0.00 $0.0012.   COMMITMENTS   On April 4, 2012, the Company issued 1.4 million common shares on a flow-through basis at a price of $28.80 per share for gross proceeds of $40.4 million.   As of September 30, 2012, the Company has spent $4.4 million on eligible expenditures and is committed to spend the remaining $36.0 million before December 31, 2013.In the normal course of business, Tourmaline is obligated to make future payments.  These obligations represent contracts and other commitments that are known and non-cancellable:                   Payments Due by Year(000s)  2012  2013  2014  2015  2016 andThereafter  TotalOperating leases $637 $2,266 $2,121 $526 $- $5,550Flow-through obligations     -     35,953     -     -     -  35,953Firm transportation agreements     7,246     29,693     21,609     12,171     1,058  71,777Bank debt(1)     -     -     -     235,382     -  235,382  $7,883 $67,912 $23,730 $248,079 $1,058 $348,662(1) Includes interest expense at an annual rate of 3.55% being the rate applicable at September 30, 2012.13.    SUBSEQUENT EVENTSOn October 9, 2012, the Company announced that it entered into a flow-through common share bought deal financing agreement.  The Company will issue 1,000,000 flow-through common shares at a price of $36.90 per share for gross proceeds of $36.9 million.  In addition, officers, directors and employees of Tourmaline will have the opportunity to purchase up to a maximum of 50,000 additional flow-through common shares at a price of $36.90 on a private placement basis.On October 23, 2012, Tourmaline entered into an agreement with Huron Energy Corp. ("Huron"), a private corporation, pursuant to which Tourmaline will acquire all of the issued and outstanding shares of Huron on the basis of 0.07644 of a Tourmaline common share for each Huron common share, which is expected to close on November 30, 2012.  The deal is subject to approval by the shareholders of the company being acquired.The acquisition will be accounted for under IFRS 3, "Business Combinations", by the acquisition method based on the fair value of the assets acquired. The initial accounting for the business combination is incomplete as the Company is in the process of evaluating the fair value of the assets acquired under IFRS in order to complete the purchase price equation for recognition, measurement and presentation in the Company's financial results for the year ended December 31, 2012.On November 7, 2012, Tourmaline closed an acquisition of a producing oil and gas asset for a cash purchase price of $84.1 million.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.SOURCE: Tourmaline Oil Corp.For further information: Tourmaline Oil Corp. Michael Rose Chairman, President and Chief Executive Officer (403) 266-5992 OR Tourmaline Oil Corp. Brian Robinson Vice President, Finance and Chief Financial Officer (403) 767-3587; robinson@tourmalineoil.com OR Tourmaline Oil Corp. Scott Kirker Secretary and General Counsel (403) 767-3593; kirker@tourmalineoil.com OR Tourmaline Oil Corp. Suite 3700, 250 - 6th Avenue S.W. Calgary, Alberta  T2P 3H7 Phone:  (403) 266-5992 Facsimile:  (403) 266-5952 Website: www.tourmalineoil.com