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Press release from CNW Group

Nexen Announces Third Quarter 2012 Results & Progress on Strategic Priorities

Thursday, October 25, 2012

Nexen Announces Third Quarter 2012 Results & Progress on Strategic Priorities05:00 EDT Thursday, October 25, 2012Met Third Quarter Production Guidance and On-Track to Meet Annual Production GuidanceCALGARY, Oct. 25, 2012 /CNW/ - Nexen Inc. (TSX, NYSE: NXY) today reported third quarter operating and financial results and provided an update on strategic priorities.Production volumes averaged 181,000 barrels of oil equivalent per day (boe/d), a decrease from second quarter production of 213,000 boe/d. This reflects the scheduled downtime associated with the turnarounds at Buzzard, Long Lake and Scott.Cash flow from operations decreased to $560 million ($1.06/share) from $707 million ($1.34/share) in the second quarter, primarily due to the lower production and higher operating costs associated with the planned turnarounds. Net income decreased to $59 million ($0.11/share) from $109 million ($0.20/share) in the second quarter. This reflects lower cash flow associated with the scheduled turnarounds and the impact of several non-recurring items.We continue to make good progress on our strategic priorities:Buzzard operations were strong prior to the turnaround with a production efficiency of 88% versus our plan of 85%.Offshore West Africa, we brought on two additional wells at Usan and increased current production to approximately 120,000 barrels per day (bbls/d) (24,000 bbls/d net to Nexen).The planned major turnaround at Long Lake was completed without any significant issues. Bitumen production is back to approximately 34,000 bbls/d and the upgrader is producing PSCTM. Pad 12 continues to ramp-up and steaming continues at pad 13. First production is expected from pad 13 over the next several weeks.In the Gulf of Mexico, we completed a successful appraisal of the south fault block at Appomattox. We are currently drilling a sidetrack to test additional resource potential in the northwest fault block.Our previously announced shale gas joint venture with INPEX Gas British Columbia Ltd. (IGBC) closed in August and we received $821 million of cash upon closing. As well, our 18-well pad in the Horn River achieved start up in late September ahead of schedule.A number of exploration wells are in progress including North Uist and Bardolph in the UK North Sea. The Owowo West prospect, offshore West Africa is currently being evaluated."In the third quarter, we announced a plan to accelerate shareholder value while remaining focused on executing our plan and advancing strategic priorities across our operations," said Kevin Reinhart, Nexen's interim President & CEO. "We completed major turnarounds at Buzzard and Long Lake, met production guidance for the fourth consecutive quarter, and remained on-track to meet our production guidance for the year. Our ability to maintain focus and make continued strong progress in key areas of our operations is a testament to the talent and exceptional dedication of Nexen employees."CNOOC Limited Offer for NexenOn July 23, 2012, Nexen entered into an Arrangement Agreement under which CNOOC Limited proposes to acquire all of the outstanding common and preferred shares of Nexen for approximately US$15 billion in cash. On September 20, 2012, holders of Nexen's common and preferred shares approved the Plan of Arrangement, pursuant to the Arrangement Agreement. The closing of the arrangement remains subject to the receipt of required regulatory approvals and the satisfaction or waiver of the other customary closing conditions. We continue to expect the arrangement to close in the fourth quarter of 2012.Operational UpdateConventional UK North Sea - Buzzard production efficiency was strong in the third quarter prior to the turnaround, averaging 88% (86% year-to-date). This exceeds our target of 85% efficiency, excluding planned downtime.The scheduled major turnaround at Buzzard that began in early September was completed with no significant issues discovered, although it did take longer than expected. We are in the process of restarting the platform, and expect production to ramp-up in the next week to 10 days.The scheduled turnaround at Scott began in late July and was completed by the end of August.The Golden Eagle development continues to progress towards first oil in late 2014. The fabrication of the platform facilities is well underway and construction is on-time and on-budget.Drilling continues on our North Uist exploration prospect, which is located west of the Shetland Islands. The well has experienced delays due to mechanical issues, and results from the BP-operated well are now expected around the end of 2012.Drilling is underway on our Bardolph exploration prospect in the North Sea. We have a 51% working interest in Bardolph. Results from this well are expected in the fourth quarter. Drilling is also underway at East Rochelle. Once drilling is completed, East Rochelle will be tied-back to our Scott platform.Offshore West Africa - In July, we spudded an exploration well at Owowo West on block OPL-223. Drilling is now complete and we are evaluating the results. This well is in close proximity to our oil discovery at Owowo South B.Oil production from Usan started in late February on block OML-138, offshore Nigeria. Nine wells are now on-stream, and during the quarter, daily production rates ranged from 90,000 - 122,000 bbls/d (18,000 - 24,000 bbls/d net to Nexen). We expect to bring on two additional wells over the next three months.Gulf of Mexico - Our top priority in the Gulf of Mexico is continuing our exploration and appraisal program in the Norphlet play, including the Appomattox structure, along with the operator, Shell Gulf of Mexico Inc.At Appomattox, we have booked 65 million barrels of probable reserves in the south fault block structure and added 50 million barrels of net contingent resource in the northeast fault block. A successful appraisal well in the south fault block of the structure confirmed reservoir quality at the upper end of our expectations. We are currently drilling a sidetrack from the appraisal well to test the incremental resource potential in the northwest fault block. Results are expected by the end of the year.We have five more exploration and appraisal targets in the Norphlet play that we plan to test over the next twelve months. These wells will allow us to progress a development plan for Appomattox and continue to test the potential of the significant acreage position we have accumulated in the area.We have a 20% interest in Appomattox, a 25% interest in Vicksburg and similar interests in numerous other blocks in the Norphlet play. The remaining interest is held by Shell.During the third quarter we concluded negotiations around the Knotty Head-Pony field unitization. Nexen was the operator of the Knotty Head portion of the field and had a 25% working interest. Under the new equity agreement, Hess Corporation is the operator of the expanded Knotty Head-Pony project and all parties have a 20% working interest. Oil Sands Long Lake - Production from Long Lake was 21,400 bbls/d of bitumen (gross), which was down from the second quarter due to the planned turnaround.The scheduled turnaround began in mid-August and was completed by early October. During the turnaround, we carried out all required regulatory inspections, scheduled maintenance and preliminary preparation for future pads as planned without any significant issues.With the turnaround complete, production is currently around 34,000 bbls/d. At pad 11, production continues to meet our expectations and recent weekly averages estimated at 6,000 bbls/d are consistent with production rates during the second quarter. At pad 12, we are currently producing from all nine wells. The nine well pairs on pad 13 are continuing to receive steam and first production is expected over the next several weeks.The cash outflow during the quarter primarily reflects the impact of the turnarounds, including the expensed portion of the related costs and reduced production. Per-barrel operating costs were higher than normal due to the lower volumes.Long Lake Quarterly Operating Metrics   BitumenProduction (Gross)(bbls/d) SteamInjection (Gross)(bbls/d) UnitOperating Cost1($/bbl) CashFlow($ millions) RealizedPrice($/bbl)2012          Q3 21,400 112,400 772 (64) 80Q2 33,700 170,000 70 4 87Q1 34,500 163,000 69 18 942011          Q4 31,500 151,000 67 22 97Q3 29,500 144,000 85 (4) 94Q2 27,900 152,000 95 6 109Q1 25,500 146,000 89 (19) 902010          Q4 28,100 158,000 86 (9) 83Q3 25,700 146,000 85 (42) 71Unit operating costs and realized prices are before royalties and based on PSC™ and bitumen volumes sold and exclude activities related to third-party bitumen purchased, processed and sold. Unit operating cost includes energy costs.Excludes costs related to the scheduled turnaround.We continue to make good progress towards filling the upgrader over the next few years with additional wells in good-quality resource:   Numberof Well Pairs Expected PeakRates bbls/d  StatusPads 12 & 13 18 11,000 - 17,000 Pad 12 is producing and pad 13 is being converted to production.Ramp-up over 12 - 24 month period.Pads 14 & 15 11 4,000 - 7,000 Drilling underway. Steam in second half of 2013.Kinosis 1A 29 15,000 - 25,000 Drilling underway. Steam in 2014.Nexen has a 65% working interest in both Long Lake and Kinosis and is the operator. CNOOC Canada Inc. holds a 35% working interest in both Long Lake and Kinosis.Shale GasNortheast British Columbia - Our previously announced joint venture agreement with IGBC closed in August. We received $821 million of cash comprised of the cash consideration, reimbursement of IGBC's share of costs since July 1, 2011 (effective date) and IGBC's carry component of our costs since July 1, 2011. There continues to be approximately $60 million of carry remaining. Upon closing, we recognized an after-tax gain of $106 million. Nexen and IGBC plan to develop our shale gas resource as economic conditions permit. We have also agreed to jointly investigate the feasibility of LNG export opportunities.We continued our execution excellence in the Horn River with the completion of our 18-well pad, setting an industry record of 6.3 fracs/day. Production testing of this pad started in late September, ahead of schedule.Production Summary  Average Daily QuarterlyProduction before Royalties Average Daily QuarterlyProduction after RoyaltiesCrude Oil, NGLs and Natural Gas (mboe/d) Q3 2012 Q2 2012 Q3 2011 Q3 2012 Q2 2012 Q3 2011UK - Buzzard 60 84 49 60 84 49UK - Other 26 30 22 26 30 22Canada - Syncrude 23 17 22 22 17 21West Africa 20 20 - 18 18 -Canada - Oil & Gas 18 20 19 17 20 17United States 14 14 21 13 13 19Canada - In Situ 14 22 19 13 20 17Other Countries 6 6 34 3 5 19Total 181 213 186 172 207 164Production decreased 15% from the second quarter on a before-royalties basis and 17% on an after-royalties basis. The decrease primarily reflects the impact of scheduled turnarounds at Long Lake, Buzzard and Scott.Guidance Update   Average Daily Production before RoyaltiesCrude Oil, NGLs and Natural Gas (mboe/d) Q1 2012Actual Q2 2012Actual Q3 2012Estimate Q3 2012Actual Q4 2012 OriginalEstimate Q4 2012Adjusted Estimate 2012 AnnualEstimateUK - Buzzard 82 84 50 - 60 60 75 - 95  50 - 60 70 - 85UK - Other 29 30 20 - 26 26 25 - 32 25 - 32 24 - 32Canada - Syncrude 21 17 22 - 24 23 22 - 24 22 - 24 21 - 23West Africa    3 20 20 - 35 20 22 - 35 22 - 30 14 - 28Canada - Oil & Gas 22 20 15 - 17 18 15 - 20 15 - 20 15 - 19United States 16 14 13 - 17 14 15 - 17 15 - 17 15 - 19Canada - In Situ 22 22 14 - 18 14 22 - 28 22 - 28 19 - 25Other Countries    7 6 2   6 2 2 2  202 213 ~160 - 190 181 ~205 - 240 ~180 - 200 ~185 - 220In the third quarter, production of 181,000 boe/d was at the upper end of our production guidance primarily due to the timing of the Buzzard turnaround.We are adjusting our fourth quarter guidance to 180,000 - 200,000 boe/d to reflect the timing and the length of the turnaround at Buzzard, as well as our updated expectations of production at Usan. Our expectations for our annual production guidance at Buzzard and Usan remain unchanged. We are also on-track to meet our annual production guidance of 185,000 - 220,000 boe/d. Buzzard, Usan and Long Lake continue to be the critical drivers of our guidance range.Financial Results  Three Months Ended  Nine Months Ended(Cdn$ millions unless noted) Sept. 302012 June 302012 Sept. 302011  Sept. 302012 Sept. 302011Brent ($US/bbl) 110.13 108.66 113.47  112.64 111.94WTI ($US/bbl) 92.22 93.49 89.76  96.21 95.48NYMEX natural gas ($US/mmbtu) 2.90 2.35 4.06  2.58 4.21Nexen Average Realized Oil & Gas Price ($/boe) 89.52 88.65 91.06  90.94 90.58Cash netback ($/boe)1 48.90 44.51 38.67  46.32 39.43Average Daily Production (mboe/d)            Before Royalties 181 213 186  199 207 After Royalties 172 207 164  190 184Cash flow from operations2  560 707 516  1,937 1,783 Per common share ($/share) 1.06 1.34 0.98  3.66 3.38Net income 59 109 200  339 654 Per common share ($/share) 0.11 0.20 0.38  0.63 1.24Capital investment3 831 743 729  2,331 1,758Net debt4 2,367 3,136 3,454  2,367 3,454Cash netback is defined as our corporate average cash netback from oil and gas operations, after-tax. Excludes costs related to the scheduled turnaround at Long Lake.For reconciliation of this non-GAAP measure, see Cash Flow from Operations on pg. 8.Includes geological and geophysical expenditures.Net debt is defined as long-term debt and short-term borrowings less cash and cash equivalents.The third quarter financial results were impacted by decreased production volumes and higher operating costs resulting from the planned turnarounds at Long Lake, Buzzard and Scott. Cash netbacks increased more than benchmark prices due to narrowing of Canadian differentials and increased contribution from our high-netback Usan production.Net income decreased 46% from the prior quarter to $59 million ($0.11/share) due to lower cash flow associated with the planned turnarounds and the impact of several non-recurring items. These include an after-tax stock-based compensation charge of $99 million as a result of our share price appreciation following the CNOOC announcement and a deferred income tax charge of $63 million for changes to UK tax legislation. These charges were partially offset by the after-tax gain of $106 million on the shale gas joint venture.Net debt decreased compared to the second quarter primarily due to the proceeds on closing of our shale gas joint venture.Quarterly Dividends The Board of Directors has declared the regular quarterly dividend of $0.05 per common share payable January 1, 2013 to shareholders of record on December 10, 2012.Due to the previously announced transaction with CNOOC Limited, the Board of Directors has determined not to declare the regular dividend on our Series 2 Preferred Shares at this time. This decision will have no effect on the amount to which holders of the Preferred Shares are entitled. If the transaction closes prior to December 31, 2012, holders of the Preferred Shares will receive consideration equal to $26 plus an amount equal to all accrued and unpaid dividends for each share held, up to but not including the date of closing. If the transaction does not close prior to December 31, 2012, the Board expects to declare a regular quarterly dividend to the shareholders of record, on a record date to be subsequently determined.About NexenNexen Inc. is a Canadian-based global energy company, listed on the Toronto and New York stock exchanges under the symbol NXY. Nexen is focused on three growth strategies: oil sands and shale gas in western Canada and conventional exploration and development primarily in the North Sea, offshore West Africa and deepwater Gulf of Mexico. Nexen adds value for shareholders through successful full-cycle oil and gas exploration and development, and leadership in ethics, integrity, governance and environmental stewardship.For further information on our shale gas joint venture, please refer to our press release dated November 29, 2011. For more information on our estimates of reserves, please refer to our 2011 Annual Information Form. For more information on our estimates of resource, please refer to our press releases dated November 15, 2010 and April 2, 2012.Forward-Looking StatementsCertain statements in this Release constitute "forward-looking statements" (within the meaning of the United States Private Securities Litigation Reform Act of 1995, as amended) or "forward-looking information" (within the meaning of applicable Canadian securities legislation). Such statements or information (together "forward-looking statements") are generally identifiable by the forward-looking terminology used such as "anticipate", "believe", "intend", "plan", "expect", "estimate", "budget", "outlook", "forecast" or other similar words and include statements relating to or associated with individual wells, regions or projects. Any statements as to possible future crude oil or natural gas prices; future production levels; future royalties and tax levels; future capital expenditures, their timing and their allocation to exploration and development activities; future earnings; future asset acquisitions or dispositions; future sources of funding for our capital program; future debt levels; availability of committed credit facilities; possible commerciality of our projects; development plans or capacity expansions; the expectation that we have the ability to substantially grow production at our oil sands facilities through controlled expansions; the expectation of achieving the production design rates from our oil sands facilities; the expectation that our oil sands production facilities continue to develop better and more sustainable practices; the expectation of cheaper and more technologically advanced operations; the expected design size of our facilities; the expected timing and associated production impact of facility turnarounds and maintenance; the expectation that we can continue to operate our offshore exploration, development and production facilities safely and profitably; future ability to execute dispositions of assets or businesses; future sources of liquidity, cash flows and their uses; future drilling of new wells; ultimate recoverability of current and long-term assets; ultimate recoverability of reserves or resources; expected finding and development costs; expected operating costs; future cost recovery oil revenues from our Yemen operations; the expectation of our ability to comply with the new safety and environmental rules enacted in the US at a minimal incremental cost, and of receiving necessary drilling permits for our US offshore operations; estimates on a per share basis; future foreign currency exchange rates; future expenditures and future allowances relating to environmental matters and our ability to comply with them; dates by which certain areas will be developed, come on stream or reach expected operating capacity; the timing and anticipated receipt of required regulatory and court  approvals for the arrangement with CNOOC Limited;  the ability of the parties to satisfy the other conditions to, and to complete, the arrangement transaction; the anticipated timing of the closing of the arrangement transaction; and changes in any of the foregoing are forward-looking statements.Statements relating to "reserves" or "resources" are forward-looking statements, as they involve the implied assessment, based on estimates and assumptions that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future.All of the forward-looking statements in this Release are qualified by the assumptions that are stated or inherent in such forward-looking statements. Although we believe that these assumptions are reasonable based on the information available to us on the date such assumptions were made, this list is not exhaustive of the factors that may affect any of the forward-looking statements and the reader should not place an undue reliance on these assumptions and such forward-looking statements. The key assumptions that have been made in connection with the forward-looking statements include the following: that we will conduct our operations and achieve results of operations as anticipated; that our development plans will achieve the expected results; the general continuance of current or, where applicable, assumed industry conditions; the continuation of assumed tax, royalty and regulatory regimes; the accuracy of the estimates of our reserve volumes; commodity price and cost assumptions; the continued availability of adequate cash flow and debt and/or equity financing to fund our capital and operating requirements as needed; the ability of the parties to the July 23 2012 Arrangement Agreement to receive, in a timely manner and on satisfactory terms, the necessary regulatory, court, stock exchange and other third party approvals, including but not limited to the receipt of applicable foreign investment approval required in Canada, the United States and elsewhere and the required approvals from the Government of the People's Republic of China and in other foreign jurisdictions; the ability of the parties to the Arrangement Agreement to satisfy, in a timely manner, the other conditions to the closing of the transaction; other expectations and assumptions concerning the arrangement transaction and the operations and capital expenditure plans of Nexen following completion of the transaction;  and, the extent of our liabilities. We believe the material factors, expectations and assumptions reflected in the forward-looking statements are reasonable, but no assurance can be given that these factors, expectations and assumptions will prove to be correct.Forward-looking statements are subject to known and unknown risks and uncertainties and other factors, many of which are beyond our control and each of which contributes to the possibility that our forward-looking statements will not occur or that actual results, levels of activity and achievements may differ materially from those expressed or implied by such statements. Such factors include, among others: market prices for oil and gas; our ability to explore, develop, produce, upgrade and transport crude oil and natural gas to markets; ultimate effectiveness of design or design modifications to facilities; the results of exploration and development drilling and related activities; the cumulative impact of oil sands development on the environment; the impact of technology on operations and processes and how new complex technology may not perform as expected; the availability of pipeline and global refining capacity; risks inherent to the operations of any large, complex refinery units, especially the integration between production operations and an upgrader facility; availability of third-party bitumen for use in our oil sands production facilities; labour and material shortages; risks related to accidents, blowouts and spills in connection with our offshore exploration, development and production activities, particularly our deep-water activities; direct and indirect risks related to the imposition of moratoriums, suspensions or cancellations of our offshore exploration, development and production operations, particularly our deep-water activities; the impact  of severe weather on our offshore exploration, development and production activities, particularly our deep-water activities; the effectiveness and reliability of our technology in harsh and unpredictable environments; risks related to the actions and financial circumstances of our agents and contractors, counterparties and joint venture partners; volatility in energy trading markets; foreign currency exchange rates; economic conditions in the countries and regions in which we carry on business; governmental actions including changes to taxes or royalties, changes in environmental and other laws and regulations including without limitation, those related to our offshore exploration, development and production activities; renegotiations of contracts; results of litigation, arbitration or regulatory proceedings; political uncertainty, including actions by terrorists, insurgent or other groups, or other armed conflict, including conflict between states; the possible failure of Nexen and CNOOC Limited to obtain necessary regulatory, court and other third party approvals, including those noted above, or to otherwise satisfy the conditions to the completion of the transaction, in a timely manner or at all; if the arrangement transaction is not completed and Nexen continues as an independent entity, there are risks that the announcement of the transaction and the dedication of substantial resources of Nexen to the completion of the transaction could have an impact on Nexen's current business relationships (including with future and prospective employees, customers, distributors, suppliers and partners) and could have a material adverse effect on the current and further operations, financial condition and prospects of Nexen; the possible failure of Nexen to comply with the terms of the Arrangement Agreement may result in Nexen being required to pay a fee to CNOOC Limited, the  result of which could have a material and adverse effect on Nexen's  financial position and results of operations and its ability to fund growth prospects and current operations; and other factors, many of which are beyond our control.These risks, uncertainties and other factors and their possible impact are discussed more fully in the sections titled "Risk Factors" in our 2011 Annual Information Form and "Quantitative and Qualitative Disclosures About Market Risk" in our 2011 annual MD&A. The impact of any one risk, uncertainty or factor on a particular forward-looking statement is not determinable with certainty as these factors are interdependent, and management's future course of action would depend on our assessment of all information at that time. Although we believe that the expectations conveyed by the forward-looking statements are reasonable based on information available to us on the date such forward-looking statements were made, no assurances can be given as to future results, levels of activity and achievements. Undue reliance should not be placed on the forward-looking statements contained herein, which are made as of the date hereof as the plans, intentions, assumptions or expectations upon which they are based might not occur or come to fruition. Except as required by applicable securities laws, Nexen undertakes no obligation to update publicly or revise any forward-looking statements, whether as a result of new information, future events or otherwise. Included herein is information that may be considered financial outlook and/or future-oriented financial information (FOFI). Its purpose is to indicate the potential results of our intentions and may not be appropriate for other purposes. The forward-looking statements contained herein are expressly qualified by this cautionary statement.Note to Investors on Reserves and ResourcesThe reserves estimates in this disclosure were prepared with an effective date of December 31, 2011.  The resource estimates were prepared on March 31, 2012.  These estimates have been internally prepared by an internal qualified reserves evaluator in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities ("NI 51-101") and the Canadian Oil and Gas Evaluation Handbook ("COGE Handbook"). For more information on this reserves estimate and Nexen's reserves estimation process please refer to our 2011 Annual Information Form. For more information on our Appomattox resource estimate please refer to our press release dated April 2, 2012. Both our Annual Information Form and news releases are available at www.nexeninc.com and www.sedar.com.Conversions of gas volumes to boe in these estimates were made on the basis of 1 boe to 6 mcf of natural gas. 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. Using the forecast prices applied to our reserves estimates, the boe conversion ratio based on wellhead value is approximately 30 mcf:1 bbl. Disclosure provided herein in respect of boes may be misleading, particularly if used in isolation.Nexen Inc.Financial Highlights    Three Months Ended  Nine Months Ended    Sept. 30  June 30  Sept. 30  Sept. 30  Sept. 30(Cdn$ millions, except per-share amounts)   2012  2012  2011  2012  2011Net Sales 1   1,495  1,659  1,399  4,850  4,546Cash Flow from Operations 1   560  707  516  1,937  1,783      Per Common Share, Basic ($/share)   1.06  1.34  0.98  3.66  3.38      Per Common Share, Diluted ($/share)   1.03  1.28  0.95  3.55  3.29Net Income 1   59  109  200  339  654      Per Common Share, Basic ($/share)   0.11  0.20  0.38  0.63  1.24Capital Investment 2   831  743  729  2,331  1,758Net Debt 3   2,367  3,136  3,454  2,367  3,454Common Shares Outstanding (millions of shares)   530.0  529.3  527.4  530.0  527.41    Includes results of discontinued operations. See Note 23 of our 2011 Annual Consolidated Financial Statements.2    Includes oil and gas development, exploration, and expenditures for other property, plant and equipment.3    Net debt is defined as long-term debt and short-term borrowings less cash and cash equivalents.Cash Flow from Operations 1    Three Months Ended  Nine Months Ended     Sept. 30  June 30  Sept. 30  Sept. 30  Sept. 30 (Cdn$ millions)   2012  2012  2011  2012  2011  Conventional Oil & Gas                       United Kingdom   737  919  645  2,721  2,231       North America   13  15  50  66  206       Other Countries 2   182  165  132  366  443 Oil Sands                       In Situ   (64)  4  (4)  (42)  (17)       Syncrude   106  70  106  267  316     974  1,173  929  3,378  3,179 Interest, Marketing and Other Corporate Items   (129)  (70)  (62)  (280)  (237)3 Current Income Taxes   (285)  (396)  (351)  (1,161)  (1,159) Cash Flow from Operations   560  707  516  1,937  1,783 1    Defined as cash flow from operating activities before changes in non-cash working capital and other. We evaluate our performance and that of our business segments based on earnings and cash flow from operations. Cash flow from operations is a non-GAAP term that represents cash generated from operating activities before changes in non-cash working capital and other. We consider it a key measure as it demonstrates our ability to generate the cash flow necessary to fund future growth through capital investment. Cash flow from operations may not be comparable with the calculation of similar measures for other companies.    Three Months Ended  Nine Months Ended    Sept. 30  June 30  Sept. 30  Sept. 30  Sept. 30(Cdn$ millions)   2012  2012  2011  2012  2011Cash Flow from Operating Activities   515  1,159  288  2,182  2,038Changes in Non-Cash Working Capital   4  (446)  198  (296)  (287)Other   53  6  38  87  56Impact of Annual Crude Oil Put Options   (12)  (12)  (8)  (36)  (24)Cash Flow from Operations   560  707  516  1,937  1,783                 Weighted Average Number of Common      Shares Outstanding, Basic (millions of shares)   530  529  527  529  527Cash Flow from Operations Per Common      Share, Basic ($/share)   1.06  1.34  0.98  3.66  3.38                 Cash Flow from Operations, Diluted   566  713  522  1,956  1,802Weighted Average Number of Common      Shares Outstanding, Diluted (millions of shares)   550  556  550  551  547Cash Flow from Operations Per Common      Share, Diluted ($/share)   1.03  1.28  0.95  3.55  3.292   Includes Nigeria, Yemen and Colombia.3   Includes results of discontinued operations. See Note 23 of our 2011 Annual Consolidated Financial Statements.Nexen Inc.Production Volumes (before royalties) 1      Three Months Ended  Nine Months Ended      Sept. 30  June 30  Sept. 30  Sept. 30  Sept. 30(mboe/d)     2012  2012  2011  2012  2011Conventional Oil and Gas                        United Kingdom     85.8  114.2  71.1  103.6  85.7      North America 2     32.3  34.4  39.7  34.9  44.8      Other Countries 3     25.8  25.5  33.9  20.3  36.8      143.9  174.1  144.7  158.8  167.3Oil Sands                        Long Lake Bitumen 4     13.9  21.9  19.2  19.4  18.0      Syncrude     22.7  17.2  21.6  20.4  21.7      36.6  39.1  40.8  39.8  39.7                   Total Production     180.5  213.2  185.5  198.6  207.0                   Total Crude Oil and Liquids (mbbls/d)     150.6  178.7  149.2  165.6  165.5Total Natural Gas (mmcf/d)     1805 207  218  1986 249                   Production Volumes (after royalties)       Three Months Ended  Nine Months Ended      Sept. 30  June 30  Sept. 30  Sept. 30  Sept. 30(mboe/d)     2012  2012  2011  2012  2011Conventional Oil and Gas                        United Kingdom     85.2  113.7  70.7  103.1  85.5      North America 2     30.0  33.1  36.0  32.8  40.7      Other Countries 3     21.3  22.9  18.9  16.9  20.5      136.5  169.7  125.6  152.8  146.7Oil Sands                        Long Lake Bitumen 4     13.2  20.4  17.3  18.2  16.6      Syncrude     22.0  16.9  20.6  19.2  20.2      35.2  37.3  37.9  37.4  36.8                   Total Production     171.7  207.0  163.5  190.2  183.5                   Total Crude Oil and Liquids (mbbls/d)     143.4  173.2  130.0  158.5  145.2Total Natural Gas (mmcf/d)     170  203  201  190  2301   We have presented production volumes before royalties as we measure our performance on this basis consistent with other Canadian oil and gas companies.2   Includes shale gas production in Canada.3   Includes Nigeria, Yemen and Colombia.4   We report Long Lake bitumen as production.5   Includes 107 mmcf/d of natural gas production in Canada, 43 in the US and 30 in the UK (2011—111, 81 and 26, respectively).6   Includes 120 mmcf/d of natural gas production in Canada, 44 in the US and 34 in the UK (2011—123, 94 and 32, respectively).Nexen Inc.Oil and Gas Prices and Cash Netbacks 1    Quarters - 2012  Quarters - 2011  TotalYear(all dollar amounts in Cdn$ unless noted)   1st  2nd  3rd  4th  1st  2nd  3rd  4th  2011PRICES:                            Brent Crude Oil (US$/bbl)   119.13  108.66  110.13     104.97  117.36  113.47  109.31  111.28WTI Crude Oil (US$/bbl)   102.93  93.49  92.22     94.10  102.56  89.76  94.06  95.12Nexen Average - Oil (Cdn$/bbl)   111.62  102.21  103.43     98.37  110.28  103.98  108.44  105.21NYMEX Natural Gas (US$/mmbtu)   2.51  2.35  2.90     4.20  4.37  4.06  3.48  4.03AECO Natural Gas (Cdn$/mcf)   2.39  1.74  2.08     3.58  3.54  3.53  3.29  3.48Nexen Average - Gas (Cdn$/mcf)   3.13  2.58  3.19     4.51  4.75  4.36  3.63  4.31NETBACKS 1:                            United Kingdom                                  Crude Oil:                                        Sales (mbbls/d)   106.9  105.3  82.1     104.2  73.3  75.2  92.7  86.3            Price Received ($/bbl)   118.12  105.82  108.39     99.97  110.67  107.58  110.46  106.76      Natural Gas:                                        Sales (mmcf/d)   33  31  31     36  37  26  22  30            Price Received ($/mcf)   7.83  6.64  7.43     7.29  8.20  7.28  6.52  7.42      Total Sales Volume (mboe/d)   112.3  110.4  87.3     110.2  79.5  79.5  96.4  91.3                                   Price Received ($/boe)   114.65  102.74  104.57     96.91  105.87  104.13  107.70  103.32      Royalties & Other   0.51  0.55  0.71     -  0.11  0.82  0.54  0.36      Operating Costs   10.14  10.90  13.78     9.85  8.48  14.46  9.99  10.60      In-country Taxes   45.41  38.84  32.04     42.46  42.76  41.00  43.24  42.41      Netback   58.59  52.45  58.04     44.60  54.52  47.85  53.93  49.95Oil Sands - In Situ 2                                  Sales (mbbls/d)   17.8  16.5  11.2     12.9  14.3  11.8  16.7  13.9                                   Price Received ($/bbl)   94.45  86.58  80.13     89.82  108.78  94.15  97.28  98.33      Royalties & Other   4.79  6.10  3.22     3.58  6.05  5.07  5.29  5.05      Operating Costs   68.89  69.95  77.363    89.43  95.34  85.42  67.41  83.44            Netback 2   20.77  10.53  (0.45)     (3.19)  7.39  3.66  24.58  9.84Oil Sands - Syncrude                                  Sales (mbbls/d)   21.3  17.2  22.7     23.2  20.4  21.6  18.2  20.8                                   Price Received ($/bbl)   92.54  89.85  91.48     94.60  111.79  97.65  104.32  101.73      Royalties & Other   11.25  (3.03)  1.84     4.30  13.82  4.65  10.59  8.10      Operating Costs   31.36  44.96  35.93     36.11  39.98  37.10  38.24  37.78            Netback   49.93  47.92  53.71     54.19  57.99  55.90  55.49  55.85United States                                  Crude Oil:                                        Sales (mbbls/d)   8.0  7.3  7.4     9.2  8.9  7.7  7.2  8.2            Price Received ($/bbl)   108.40  102.19  99.04     91.39  101.89  96.00  110.89  99.65      Natural Gas:                                        Sales (mmcf/d)   50  41  43     103  96  81  66  86            Price Received ($/mcf)   2.67  2.19  2.89     4.36  4.42  4.27  3.59  4.21      Total Sales Volume (mboe/d)   16.3  14.1  14.5     26.3  24.9  21.2  18.2  22.6                                   Price Received ($/boe)   61.33  58.84  58.91     48.91  53.56  50.72  57.27  52.31      Royalties & Other   6.02  6.12  6.50     5.65  6.11  5.63  3.31  5.30      Operating Costs   17.29  17.87  19.37     10.43  10.72  11.18  16.73  11.96      Netback   38.02  34.85  33.04     32.83  36.73  33.91  37.23  35.051   Netbacks are defined as average sales price less royalties, other operating costs and in-country taxes.2   Excludes activities related to third-party bitumen purchased, processed and sold.3   Excludes costs related to turnaround activities.Nexen Inc.Oil and Gas Cash Netback 1(continued)    Quarters - 2012  Quarters - 2011  TotalYear(all dollar amounts in Cdn$ unless noted)   1st  2nd  3rd  4th  1st  2nd  3rd  4th  2011Canada - Natural Gas 2                                  Sales (mmcf/d)   131  120  105     97  85  79  112  93                                   Price Received ($/mcf)   2.12  1.67  2.05     3.65  3.62  3.51  3.08  3.44      Royalties & Other   0.08  (0.05)  0.06     0.28  0.24  0.27  0.17  0.23      Operating Costs   1.58  1.62  1.72     1.70  1.54  1.65  1.70  1.65      Netback   0.46  0.10  0.27     1.67  1.84  1.59  1.21  1.56Other Countries 3                                  Sales (mbbls/d)   5.4  27.0  27.4     36.7  41.0  33.5  29.4  35.1                                   Price Received ($/bbl)   119.61  105.59  109.24     101.17  111.56  107.64  111.10  107.85      Royalties & Other   48.76  17.27  18.44     44.95  50.38  47.54  43.83  46.92      Operating Costs   13.02  17.70  14.42     10.62  9.23  12.97  19.89  12.73      In-country Taxes   9.31  2.50  1.94     12.81  15.58  14.71  13.27  14.17      Netback   48.52  68.12  74.44     32.79  36.37  32.42  34.11  34.03Company-Wide                                  Oil and Gas Sales (mboe/d)   195.0  205.2  180.6     225.5  194.3  180.7  197.6  199.2                                   Price Received ($/boe)   94.67  88.65  89.52     85.98  95.31  91.06  94.11  91.46      Royalties & Other   3.87  3.19  4.12     8.74  13.47  10.83  8.62  10.34      Operating Costs   18.56  19.74  20.714    17.32  18.68  20.80  19.56  19.00      In-country Taxes   26.43  21.21  15.79     22.84  20.78  20.76  23.08  21.92      Netback   45.81  44.51  48.90     37.08  42.38  38.67  42.85  40.201   Netbacks are defined as average sales price less royalties and other, operating costs and in-country taxes.2   Includes Canadian conventional, CBM and shale gas activities. Shale gas was included beginning in the fourth quarter of 2011 when it became commercial.3   Includes Yemen, Colombia and West Africa.4   Excludes costs related to turnaround activities.Nexen Inc.Unaudited Condensed Consolidated Statement of IncomeFor the Three and Nine Months Ended September 30    Three MonthsEnded September 30   Nine MonthsEnded September 30(Cdn$ millions, except per-share amounts)   2012  2011   2012  2011Revenues and Other Income                    Net Sales   1,495  1,399   4,850  4,504      Marketing and Other Income (Note 8)   14  125   165  254    1,509  1,524   5,015  4,758Expenses                    Operating   401  356   1,116  1,060      Depreciation, Depletion, Amortization and Impairment   427  409   1,312  1,114      Transportation and Other   128  110   353  289      General and Administrative   223  23   464  204      Exploration   49  59   264  278      Finance (Note 5)   80  59   225  193      Loss on Debt Redemption and Repurchase   -  -   -  91      Gain from Dispositions (Note 10)   (145)  -   (197)  (12)    1,163  1,016   3,537  3,217               Income from Continuing Operations before Provision      for Income Taxes   346  508   1,478  1,541               Provision for (Recovery of) Income Taxes                    Current   285  351   1,161  1,159      Deferred   2  (43)   (22)  30    287  308   1,139  1,189               Net Income from Continuing Operations   59  200   339  352Net Income from Discontinued Operations, Net of Tax   -  -   -  302Net Income Attributable to Nexen Inc. Shareholders   59  200   339  654               Earnings Per Common Share from Continuing      Operations ($/share) (Note 6)                          Basic   0.11  0.38   0.63  0.67                           Diluted   0.11  0.32   0.63  0.61               Earnings Per Common Share ($/share) (Note 6)                          Basic   0.11  0.38   0.63  1.24                           Diluted   0.11  0.32   0.63  1.16See accompanying notes to the Unaudited Condensed Consolidated Financial Statements. Nexen Inc.Unaudited Condensed Consolidated Balance Sheet         September 30   December 31(Cdn$ millions)        2012   2011Assets                   Current Assets                         Cash and Cash Equivalents        1,870   845            Restricted Cash        18   45            Accounts Receivable        1,582   2,247            Derivative Contracts        62   119            Inventories and Supplies        351   320            Other        140   115                  Total Current Assets        4,023   3,691      Non-Current Assets                         Property, Plant and Equipment (Note 3)        15,462   15,571            Goodwill        282   291            Deferred Income Tax Assets        482   338            Derivative Contracts        4   25            Other Long-Term Assets        98   152Total Assets        20,351   20,068              Liabilities                    Current Liabilities                         Accounts Payable and Accrued Liabilities        2,591   2,867            Income Taxes Payable        609   458            Derivative Contracts        63   103                  Total Current Liabilities        3,263   3,428      Non-Current Liabilities                         Long-Term Debt        4,237   4,383            Deferred Income Tax Liabilities        1,574   1,488            Asset Retirement Obligations        1,973   2,010            Derivative Contracts        4   24            Other Long-Term Liabilities        452   362Equity (Note 6)                         Share Capital                               Common Shares        1,194   1,157                  Preferred Shares        195   -            Retained Earnings        7,465   7,211            Cumulative Translation Adjustment        (6)   5      Total Equity        8,848   8,373Total Liabilities and Equity        20,351   20,068See accompanying notes to Unaudited Condensed Consolidated Financial Statements. Nexen Inc.Unaudited Condensed Consolidated Statement of Cash FlowsFor the Three and Nine Months Ended September 30    Three MonthsEnded September 30   Nine MonthsEnded September 30(Cdn$ millions)   2012  2011   2012  2011Operating Activities                    Net Income from Continuing Operations   59  200   339  352      Net Income from Discontinued Operations   -  -   -  302      Charges and Credits to Income not Involving Cash (Note 9)   464  265   1,370  875      Exploration Expense   49  59   264  278      Changes in Non-Cash Working Capital (Note 9)   (4)  (198)   296  287      Other   (53)  (38)   (87)  (56)    515  288   2,182  2,038               Financing Activities                    Repayment of Long-Term Debt   -  -   -  (871)      Issue of Common Shares   11  8   37  39      Issue of Preferred Shares   -  -   195  -      Dividends Paid on Common and Preferred Shares   (29)  (26)   (82)  (78)      Other   -  1   (6)  2    (18)  (17)   144  (908)               Investing Activities                    Capital Expenditures                          Exploration, Evaluation and Development   (807)  (716)   (2,261)  (1,708)            Corporate and Other   (24)  (13)   (70)  (50)      Proceeds from Dispositions (Note 10)   828  1   881  475      Changes in Restricted Cash   83  1   27  (10)      Changes in Non-Cash Working Capital (Note 9)   75  69   140  184      Other   (2)  -   3  (75)    153  (658)   (1,280)  (1,184)               Effect of Exchange Rate Changes on Cash and Cash Equivalents   (35)  100   (21)  74               Increase (Decrease) in Cash and Cash Equivalents   615  (287)   1,025  20               Cash and Cash Equivalents - Beginning of Period   1,255  1,312   845  1,005               Cash and Cash Equivalents - End of Period 1   1,870  1,025   1,870  1,0251   Cash and cash equivalents at September 30, 2012 consists of cash of $620 million and short-term investments of $1,250 million (September 30, 2011 cash of $277 million and short-term investments of $748 million).See accompanying notes to the Unaudited Condensed Consolidated Financial Statements.Nexen Inc.Unaudited Condensed Consolidated Statement of Changes in EquityFor the Three and Nine Months Ended September 30      Three MonthsEnded September 30   Nine MonthsEnded September 30(Cdn$ millions)     2012  2011   2012  2011                 Share Capital                      Common Shares, Beginning of Period     1,183  1,142   1,157  1,111            Issue of Common Shares     11  8   37  39      Common Shares, Balance at End of Period     1,194  1,150   1,194  1,150                       Preferred Shares, Beginning of Period     195  -   -  -            Issue of Preferred Shares     -  -   195  -      Preferred Shares, Balance at End of Period     195  -   195  -                 Retained Earnings, Beginning of Period     7,435  7,094   7,211  6,692            Net Income Attributable to Nexen Inc. Shareholders     59  200   339  654            Dividends on Common and Preferred Shares (Note 6)     (29)  (26)   (85)  (78)      Balance at End of Period     7,465  7,268   7,465  7,268                 Cumulative Translation Adjustment, Beginning of Period     26  (55)   5  (37)            Currency Translation Adjustment     (35)  63   (30)  45            Realized Translation Adjustments 1     3  -   19  -      Balance at End of Period     (6)  8   (6)  81  Net of income tax recovery for the three months ended September 30, 2012 of $2 million (2011 - net of income tax expense of $4 million) and net of income tax recovery for the nine months ended September 30, 2012 of $9 million (2011 - net of income tax expense of $24 million).See accompanying notes to the Unaudited Condensed Consolidated Financial Statements.Nexen Inc.Unaudited Condensed Consolidated Statement of Comprehensive IncomeFor the Three and Nine Months Ended September 30     Three MonthsEnded September 30   Nine MonthsEnded September 30(Cdn$ millions)    2012  2011   2012  2011Net Income Attributable to Nexen Inc. Shareholders    59  200   339  654      Other Comprehensive Income (Loss):                           Currency Translation Adjustment                                 Net Translation Gains (Losses) of Foreign Operations    (163)  339   (149)  200                  Net Translation Gains (Losses) on US$-Denominated                     Debt Hedging of Foreign Operations 1    128  (276)   119  (155) Total Currency Translation Adjustment    (35)  63   (30)  45Total Comprehensive Income    24  263   309  6991  Net of income tax expense for the three months ended September 30, 2012 of $18 million (2011 - net of income tax recovery of $39 million) and net of income tax expense for the nine months ended September 30, 2012 of $17 million (2011 - net of income tax recovery of $22 million).See accompanying notes to the Unaudited Condensed Consolidated Financial Statements.Nexen Inc.Notes to Unaudited Condensed Consolidated Financial StatementsCdn$ millions, except as noted1. BASIS OF PRESENTATIONNexen Inc. (Nexen, we or our) is an independent, global energy company with operations in the UK North Sea, US Gulf of Mexico, offshore Nigeria, Canada, Yemen, Colombia and Poland. Nexen is incorporated and domiciled in Canada and our head office is located at 801—7th Avenue SW, Calgary, Alberta, Canada. Nexen's shares are publicly traded on both the Toronto Stock Exchange and the New York Stock Exchange.These Unaudited Condensed Consolidated Financial Statements for the three and nine months ended September 30, 2012 have been prepared in accordance with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB). Specifically, they have been prepared in accordance with International Accounting Standard (IAS) 34 Interim Financial Reporting. The Unaudited Condensed Consolidated Financial Statements do not include all of the information required for annual financial statements and should be read in conjunction with the Audited Consolidated Financial Statements for the year ended December 31, 2011, which have been prepared in accordance with IFRS.CNOOC Acquisition of NexenOn July 23, 2012, Nexen and CNOOC Limited (CNOOC) entered into an Arrangement Agreement in which CNOOC proposed to acquire all of the outstanding shares of Nexen Inc. for US$27.50 per common share and Cdn$26.00 per preferred share. The transaction is proposed to be completed by way of a plan of arrangement (the "Arrangement") under the Canada Business Corporations Act.  On September 20, 2012, Nexen's common and preferred shareholders approved the Arrangement, and the Court of Queen's Bench of Alberta granted a final order approving the Arrangement. The closing of the Arrangement remains subject to the receipt of required regulatory approvals and the satisfaction or waiver of the other customary closing conditions.The Unaudited Condensed Consolidated Financial Statements were authorized for issue by Nexen's Board of Directors on October 24, 2012.2. ACCOUNTING POLICIESThe accounting policies we follow are described in Note 2 of the Audited Consolidated Financial Statements for the year ended December 31, 2011. There have been no changes to our accounting policies since December 31, 2011.3.PROPERTY, PLANT AND EQUIPMENT (PP&E)(a)  Carrying amount of PP&E    ExplorationandEvaluation  AssetsUnderConstruction  ProducingOil & GasProperties  Corporateand Other    TotalCost                     As at December 31, 2011   2,206  2,347  19,832  837    25,222         Additions   546  581  1,134  70    2,331         Disposals/Derecognitions   (187)  -  (925)  (15)    (1,127)         Transfers 1   -  (1,862)  1,862  -    -         Exploration Expense   (264)  -  -  -    (264)         Other   (6)  -  90  18    102         Effect of Changes in Exchange Rate   (39)  (32)  (375)  (7)    (453)   As at September 30, 2012   2,256  1,034  21,618  903    25,811                   Accumulated Depreciation, Depletion &   Amortization (DD&A)                     As at December 31, 2011   368  -  8,860  423    9,651         DD&A   44  -  1,203  65    1,312         Disposals/Derecognitions   (16)  -  (307)  (12)    (335)         Other   -  -  (27)  17    (10)         Effect of Changes in Exchange Rate   (11)  -  (253)  (5)    (269)   As at September 30, 2012   385  -  9,476  488    10,349                   Net Book Value                     As at December 31, 2011   1,838  2,347  10,972  414    15,571   As at September 30, 2012   1,871  1,034  12,142  415    15,4621   Includes PP&E costs related to our Usan development, offshore Nigeria which came on-stream February 2012.Exploration and evaluation assets mainly comprise of unproved properties and capitalized exploration drilling costs. Assets under construction at September 30, 2012 primarily include our developments in the UK North Sea.(b)  ImpairmentDD&A expense for the third quarter of 2011 includes non-cash impairment charges of $141 million for our Canadian coalbed methane and conventional gas assets. Sustained lower natural gas prices in the quarter reduced our estimates of fair value and resulted in impairment of the properties' carrying value.4.LONG-TERM DEBT During the three and nine months ended September 30, 2012, we borrowed and repaid nil and $254 million on our term credit facilities, respectively. We recorded $146 million and $136 million, respectively, of unrealized foreign exchange gains on long-term debt in other comprehensive income.We have undrawn, committed, unsecured term credit facilities of $3.7 billion, of which $700 million is available until 2014 and $3.0 billion is available until 2017. As at September 30, 2012, $232 million of our term credit facilities were utilized to support letters of credit (December 31, 2011—$367 million).Nexen has undrawn, uncommitted, unsecured credit facilities of approximately $180 million. We utilized $5 million of these facilities to support outstanding letters of credit at September 30, 2012 (December 31, 2011—$17 million).Nexen has undrawn, uncommitted, unsecured credit facilities of approximately $207 million exclusively to support letters of credit. We utilized $16 million of these facilities to support outstanding letters of credit at September 30, 2012 (December 31, 2011—$4 million).5.FINANCE EXPENSE      Three MonthsEnded September 30   Nine MonthsEnded September 30      2012  2011   2012  2011Interest on Long-Term Debt     75  73   223  231Accretion Expense Related to Asset Retirement Obligations     13  12   39  35Other Interest and Fees     6  7   18  17Total     94  92   280  283      Less: Capitalized at 6.7% (2011 — 6.7%)     (14)  (33)   (55)  (90)Total      80  59   225  193                 Capitalized interest relates to and is included as part of the cost of our oil and gas properties. The capitalization rates are based on our weighted-average cost of borrowings.6.EQUITY(a)  Common SharesAuthorized share capital consists of an unlimited number of common shares of no par value. At September 30, 2012, there were 530,005,285 common shares outstanding (December 31, 2011—527,892,635 common shares).(b)  Preferred SharesAuthorized share capital consists of an unlimited number of Class A preferred shares of no par value, issuable in series. At September 30, 2012, there were 8,000,000 Cumulative Redeemable Class A Rate Reset Preferred Shares, Series 2 outstanding (December 31, 2011—nil).(c)  Earnings Per Common Share (EPS)We calculate basic EPS using net income attributable to Nexen Inc. common shareholders, adjusted for preferred share dividends and divided by the weighted-average number of common shares outstanding. We calculate diluted EPS in the same manner as basic, except we adjust basic earnings for the potential conversion of the subordinated debentures and potential exercise of outstanding tandem options for shares, if dilutive. We use the weighted-average number of diluted common shares outstanding in the denominator of our diluted EPS calculation.      Three MonthsEnded September 30   Nine MonthsEnded September 30(Cdn$ millions)     2012  2011   2012  2011Net Income Attributable to Nexen Inc. Common Shareholders     59  200   339  654      Preferred Share Dividends Payable     (3)  -   (6)  -Net Income Attributable to Nexen Inc. Common     Shareholders, Basic     56  200   333  654      Potential Tandem Options Exercises     -  (29)   -  (39)      Potential Conversion of Subordinated Debentures     -  6   -  19Net Income Attributable to Nexen Inc. Common       Shareholders, Diluted     56  177   333  634                 (millions of shares)                Weighted Average Number of Common Shares      Outstanding, Basic     530  527   529  527      Common Shares Issuable Pursuant to Tandem Options     -  2   -  2      Common Shares Notionally Purchased from Proceeds of            Tandem Options     -  (2)   -  (2)      Common Shares Issuable Pursuant to Potential Conversion            of Subordinated Debentures     -  23   -  20Weighted Average Number of Common Shares      Outstanding, Diluted     530  550   529  547                 In calculating the weighted-average number of diluted common shares outstanding and related earnings adjustments for the three and nine months ended September 30, 2012, we excluded 8,118,453 and 11,390,032 tandem options, respectively (2011—15,162,013 and 15,081,166, respectively) because their exercise price was greater than the average common share market price during those periods. During the three and nine months ended September 30, 2012, there were no dilutive instruments. During the three and nine months ended September 30, 2011, the potential conversion of tandem options and subordinated debentures were the only dilutive instruments.(d)  DividendsWe paid dividends of $0.05 and $0.15 per common share, for the three and nine months ended September 30, 2012 ($0.05 and $0.15 per common share for the respective periods ended September 30, 2011).We paid dividends of $0.3928 per preferred share, for the three and nine months ended September 30, 2012 (nil paid per preferred share for the respective periods ended September 30, 2011).Dividends paid to holders of common and preferred shares have been designated as "eligible dividends" for Canadian tax purposes.On October 24, 2012, the Board of Directors declared a quarterly dividend of $0.05 per common share, payable January 1, 2013 to the shareholders of record on December 10, 2012.(e)  Stock-Based Compensation      Three Months Ended September 30, 2012(thousands of shares)     Options   STARs   RSUs   PSUsOutstanding, Beginning of Period     14,966   13,584   3,793   599  Granted     -   -   23   -  Exercised for Stock     (107)   -   -   -  Exercised or Redeemed for Cash     (510)   (822)   (1)   -  Cancelled     (169)   (252)   (119)   (14)  Expired     -   (13)   -   -Outstanding, End of Period     14,180   12,497   3,696   585                         Nine Months Ended September 30, 2012(thousands of shares)     Options   STARs   RSUs   PSUsOutstanding, Beginning of Period     14,854   14,407   2,025   390  Granted     1,368   339   1,936   312  Exercised for Stock     (107)   -   -   -  Exercised or Redeemed for Cash     (552)   (962)   (4)   -  Cancelled     (1,333)   (1,173)   (261)   (117)  Expired     (50)   (114)   -   -Outstanding, End of Period     14,180   12,497   3,696   585                   Exercisable, End of Period     7,710   8,729                           Options and STARs granted in the nine months ended September 30, 2012 have a weighted average exercise price of $19.26/unit. No options or STARs were granted during the three months ended September 30, 2012. We recognized compensation expense related to share-based payments in the amount of $116 and $140 million (2011—compensation recovery $65 and $62 million) for the three and nine months ended September 30, 2012, respectively.7.COMMITMENTS, CONTINGENCIES AND GUARANTEESAs described in Note 19 to the 2011 Audited Consolidated Financial Statements, there are a number of lawsuits and claims pending, the ultimate results of which cannot be ascertained at this time. We record costs as they are incurred or become determinable. We believe that payments, if any, related to existing indemnities would not have a material adverse effect on our liquidity, financial condition or results of operations.We assume various contractual obligations and commitments in the normal course of our operations. During the quarter, we entered into drilling rig commitments comprised of the following:         2012    2013    2014    2015    2016  ThereafterDrilling Rig Commitments        17    60    23    9    -  -The commitments above are in addition to those included in Note 19 to the 2011 Audited Consolidated Financial Statements and Note 7 to the Unaudited Condensed Consolidated Financial Statements for the three months ended March 31, 2012 and June 30, 2012.8. MARKETING AND OTHER INCOME         Three MonthsEnded September 30   Nine MonthsEnded September 30         2012  2011   2012  2011Marketing Revenue, Net        35  72   210  174Interest Income        15  -   16  3Foreign Exchange Gains (Losses)        (55)  30   (59)  14Change in Fair Value of Crude Oil Put Options        (4)  13   (38)  6Insurance Proceeds        -  -   -  26Other        23  10   36  31Total         14  125   165  2549. CASH FLOWS(a)  Charges and credits to income not involving cash       Three MonthsEnded September 30   Nine MonthsEnded September 30       2012  2011   2012  2011Depreciation, Depletion, Amortization and Impairment      427  409   1,312  1,114Gain from Dispositions      (145)  -   (197)  (12)Change in Fair Value of Crude Oil Put Options      4  (13)   38  (6)Non-cash Stock-Based Compensation (Recovery)      108  (65)   132  (67)Foreign Exchange      51  (31)   59  (14)Provision for (Recovery of) Deferred Income Taxes      2  (43)   (22)  30Loss on Debt Redemption and Repurchase      -  -   -  91Non-Cash Items Included in Discontinued Operations      -  -   -  (290)Other      17  8   48  29Total      464  265   1,370  875                  (b)  Changes in non-cash working capital       Three MonthsEnded September 30   Nine MonthsEnded September 30       2012  2011   2012  2011Accounts Receivable      294  61   807  (73)Inventories and Supplies      (105)  (3)   (65)  181Other Current Assets      (6)  (4)   (23)  (13)Accounts Payable and Accrued Liabilities      143  114   (403)  283Current Income Taxes Payable      (255)  (297)   120  93Total      71  (129)   436  471                  Relating to:                       Operating Activities      (4)  (198)   296  287      Investing Activities      75  69   140  184Total      71  (129)   436  471                  (c)  Other cash flow information           Three MonthsEnded September 30   Nine MonthsEnded September 30           2012  2011   2012  2011Interest Paid          89  88   237  218Income Taxes Paid          527  646   1,024  1,10610. DISPOSITIONSAsset DispositionsCanadian Shale Gas Joint VentureDuring the quarter, we closed the sale of a 40% working interest in our northeast British Columbia shale gas operations to INPEX Gas British Columbia Ltd. (IGBC). Upon closing we received $821 million in cash, comprised of the initial cash payment, the carry associated with Nexen's capital and IGBC's share of costs since the July 1, 2011 effective date of the transaction. We recorded a pre-tax gain on sale of $142 million on closing.11.OPERATING SEGMENTS AND RELATED INFORMATIONNexen has the following operating segments:Conventional Oil and Gas: We explore for, develop and produce crude oil and natural gas from conventional sources around the world. Our operations are focused in the UK North Sea, North America (Canada and US) and other countries (offshore Nigeria, Colombia, Yemen and Poland).Oil Sands: We develop and produce synthetic crude oil from the Athabasca oil sands in northern Alberta. We produce bitumen using in situ and mining technologies and upgrade it into synthetic crude oil before ultimate sale. Our in situ activities are comprised of our operations at Long Lake and future development phases. Our mining activities are conducted through our 7.23% ownership of the Syncrude Joint Venture.Shale Gas: We explore for and produce unconventional gas from shale formations in northeast British Columbia. Production and results of operations are included within Conventional Oil and Gas until they become significant.Corporate and Other includes energy marketing and unallocated items. The results of Canexus have been presented as discontinued operations.The accounting policies of our operating segments are the same as those described in Note 2 of our Audited Consolidated Financial Statements for the year ended December 31, 2011. Net income (loss) of our operating segments excludes interest income, interest expense, income tax expense, unallocated corporate expenses and foreign exchange gains and losses. Identifiable assets are those used in the operations of the segments.Segmented net income for the three months ended September 30, 2012    Conventional   Oil SandsCorporate andOther     Total     UnitedKingdom   NorthAmerica   OtherCountries1  In Situ   Syncrude                                     Net Sales   834   90   228   143   18812     1,495 Marketing and Other Income   20   3   -   -   -(9)     14     854   93   228   143   1883     1,509                              Less: Expenses                               Operating   111   42   37   1312  755     401    Depreciation, Depletion and         Amortization   157   65   133   40   1715     427    Transportation and Other   (1)   14   -   66   643     128    General and Administrative   17   46   26   21   11123    223    Exploration   11   28   94  1   --     49    Finance   6   3   -   1   268     80    Gain from Dispositions   (2)   (143)   -   -   --     (145) Income (Loss) before    Income Taxes   555   38   23   (117)   87(240)     346  Less: Provision for Income Taxes                            2875 Net Income                           59                               Capital Expenditures   270   178   896  217   6710     831 1  Includes results of operations in Nigeria, Yemen and Colombia.2  Includes Long Lake turnaround costs of $49 million.3  Includes non-cash stock-based compensation expense of $108 million.4 Includes exploration activities primarily in Colombia and Poland.5 Includes UK current tax expense of $278 million.6 Includes capital expenditures in Nigeria of $63 million.Segmented net income for the three months ended September 30, 2011    Conventional  Oil SandsCorporate andOther     Total     UnitedKingdom   NorthAmerica   OtherCountries1, 2  In Situ   Syncrude                                     Net Sales   756   112   185   146   18515     1,399 Marketing and Other Income   -   4   5   -   2114     125     756   116   190   146   187129     1,524                              Less: Expenses                               Operating   106   34   39   97   737     356    Depreciation, Depletion,         Amortization and Impairment   124   210   18   30   1611     409    Transportation and Other   5   10   7   49   633     110    General and Administrative   (7)   3   2   (1)   125     23    Exploration   15   17   273  -   --     59    Finance   6   5   -   1   146     59 Income (Loss) before    Income Taxes   507   (163)   97   (30)   907     508 Less: Provision for Income Taxes                          3084Net Income                           200                              Capital Expenditures   190   243   1615  90   3411     729 1  Includes results of operations in Yemen and Colombia.2  Includes Yemen Masila net sales of $138 million and net income before taxes of $52 million.3  Includes exploration activities primarily in Norway, Colombia and Poland.4  Includes UK current tax expense of $299 million.5  Includes capital expenditures in Nigeria of $135 million.Segmented net income for the nine months ended September 30, 2012    Conventional  Oil SandsCorporate andOther     Total     UnitedKingdom   NorthAmerica   OtherCountries1  In Situ   Syncrude                                     Net Sales   3,028   284   479   534   49134     4,850 Marketing and Other Income   29   6   -   -   1129     165     3,057   290   479   534   492163     5,015                              Less: Expenses                               Operating   324   127   89   3522  20618     1,116    Depreciation, Depletion and         Amortization   627   203   251   140   4942     1,312    Transportation and Other   4   30   -   194   18107     353    General and Administrative   25   92   44   43   12593    464    Exploration   41   205   174  1   --     264    Finance   18   11   1   2   6187     225    Gain from Dispositions   (2)   (156)   (7)   (32)   --     (197) Income (Loss) before    Income Taxes   2,020   (222)   84   (166)   212(450)     1,478 Less: Provision for Income Taxes                          1,1395Net Income                           339                               Capital Expenditures   708   610   3416  493   14930     2,331 1  Includes results of operations in Nigeria, Yemen and Colombia.2  Includes Long Lake turnaround costs of $49 million.3  Includes non-cash stock-based compensation expense of $132 million.4 Includes exploration activities primarily in Colombia and Poland, and recovery of previously expensed exploration costs in Norway.5 Includes UK current tax expense of $1,134 million.6 Includes capital expenditures in Nigeria of $250 million.Segmented net income for the nine months ended September 30, 2011    Conventional  Oil SandsCorporate andOther     Total     UnitedKingdom   NorthAmerica   OtherCountries1, 2  In Situ   Syncrude                                     Net Sales   2,482   379   599   449   55540     4,504 Marketing and Other Income   9   36   12   -   3194     254     2,491   415   611   449   558234     4,758                              Less: Expenses                               Operating   265   110   109   331   22322     1,060    Depreciation, Depletion,         Amortization and Impairment   439   431   66   95   4637     1,114    Transportation and Other   5   25   23   118   18100     289    General and Administrative   (17)   55   25   12   1128     204    Exploration   32   117   1273  2   --     278    Finance   16   13   1   2   4157     193    Loss on Debt Redemption   -   -   -   -   -91     91    Gain from Dispositions   (8)   -   -   -   -(4)     (12) Income (Loss) before    Income Taxes   1,759   (336)   260   (111)   266(297)     1,541 Less: Provision for Income Taxes                          1,1894Income from Continuing Operations                          352 Add: Net Income from Discontinued   Operations                          302 Net Income                           654                              Capital Expenditures   368   485   4785  310   8037     1,758 1 Includes results of operations in Yemen and Colombia.2 Includes Yemen Masila net sales of $453 million and net income before taxes of $192 million.3 Includes exploration activities primarily in Norway, Colombia and Poland.4 Includes UK current tax expense of $1,047 million.5 Includes capital expenditures in Nigeria of $349 million.Segmented assets as at September 30, 2012    Conventional  Oil SandsCorporate andOther     Total    UnitedKingdom   NorthAmerica   OtherCountries   In Situ   Syncrude                                   Total Assets   5,039   2,913   2,250   6,243   1,5182,3881    20,351                            Property, Plant and Equipment                              Cost   7,534   6,514   2,799   6,407   1,878679     25,811   Less: Accumulated DD&A   4,127   4,131   878   330   456427     10,349Net Book Value   3,407   2,3832  1,9213  6,0774  1,422252     15,4621 Includes cash of $1,039 million, and Energy Marketing accounts receivable, current derivative assets and inventory of $835 million.2 Includes net book value of $827 million associated with our Canadian shale gas operations.3 Includes net book value of $1,774 million related to our Usan development, offshore Nigeria.4 Includes net book value of $5,228 million for Long Lake Phase 1 and $849 million for future phases of our in situ oil sands projects.Segmented assets as at December 31, 2011    Conventional  Oil SandsCorporate andOther     Total    UnitedKingdom   NorthAmerica   OtherCountries   In Situ   Syncrude                                   Total Assets   4,817   3,403   2,138   5,881   1,4232,4061    20,068                            Property, Plant and Equipment                              Cost   7,103   7,256   2,566   5,915   1,733649     25,222   Less: Accumulated DD&A   3,707   4,299   648   205   411381     9,651Net Book Value   3,396   2,9572  1,9183  5,7104  1,322268     15,5711 Includes cash of $453 million, and Energy Marketing accounts receivable, current derivative assets and inventory of $1,449 million.2 Includes net book value of $1,293 million associated with our Canadian shale gas operations.3 Includes net book value of $1,821 million related to our Usan development, offshore Nigeria.4 Includes net book value of $5,050 million for Long Lake Phase 1 and $660 million for future phases of our in situ oil sands projects.       SOURCE: Nexen Inc.For further information: For investor relations inquiries, please contact:Janet Craig Vice President, Investor Relations (403) 699-4230 For media and general inquiries, please contact:Pierre Alvarez  Vice President, Corporate Relations (403) 699-5202 801 - 7th Ave SW Calgary, Alberta, Canada T2P 3P7 www.nexeninc.com