Murphy Oil Corporation (NYSE: MUR) announced today that its net income in the fourth quarter of 2012 was $158.7 million ($0.82 per diluted share) compared to a net loss of $113.9 million ($0.59 per diluted share) in the fourth quarter of 2011. Net income in the fourth quarter of 2012 was improved over the same 2011 quarter principally due to lower impairment expenses and income tax benefits associated with operating losses in two foreign countries in the current period. The just completed quarter included total impairment charges of $261.0 million ($239.6 million after taxes) associated with both oil production operations in Republic of the Congo and ethanol production operations in Hereford, Texas. The Congo impairment related primarily to unsuccessful drilling operations in the fourth quarter and the removal of proved oil reserves at year-end 2012 at the Azurite field. The field continues to produce while we evaluate future options. Operating results in the fourth quarter of the prior year included an impairment charge for Azurite of $368.6 million. The Hereford ethanol plant was deemed impaired at year-end 2012 due to an expectation of weak future ethanol crush spreads. Income tax benefits in the upstream business totaled $108.3 million associated with tax deductions for operating losses in Republic of the Congo and Suriname. The 2012 fourth quarter included a loss from discontinued operations of $3.7 million ($0.02 per diluted share), compared to income from discontinued operations of $4.0 million ($0.02 per diluted share) in the 2011 quarter. Income from continuing operations in the fourth quarter of 2012 was $162.4 million ($0.84 per diluted share), but was a loss of $117.9 million ($0.61 per diluted share) a year ago.
For the year of 2012, net income totaled $970.9 million ($4.99 per diluted share) compared to $872.7 million ($4.49 per diluted share) in 2011. Net income included income from discontinued operations of $6.8 million ($0.04 per diluted share) in 2012 and $143.2 million ($0.74 per diluted share) in 2011. Income from continuing operations for the years of 2012 and 2011 totaled $964.1 million ($4.95 per diluted share) and $729.5 million ($3.75 per diluted share), respectively.
|Three Months Ended||Years Ended|
|(Millions of Dollars)|
|Exploration and Production||$||145.0||(144.6||)||905.0||614.2|
|Refining and Marketing||38.5||61.0||157.6||190.3|
|Income (loss) from continuing operations||162.4||(117.9||)||964.1||729.5|
|Income (loss) from discontinued operations|
|Net income (loss)|
|Income (loss) per Common share – Diluted:|
|Income (loss) from continuing operations||$||0.84||(0.61||)||4.95||3.75|
|Net income (loss)||0.82||(0.59||)||4.99||4.49|
Fourth quarter 2012 vs. Fourth quarter 2011
Exploration and Production (E&P)
Income for the Company’s E&P continuing operations was $145.0 million in the fourth quarter of 2012 compared to a loss of $144.6 million in the same quarter of 2011. The improvement in earnings in the fourth quarter 2012 compared to the same period in 2011 was primarily attributable to a larger impairment charge in Republic of the Congo in 2011 and income tax benefits recognized in 2012 totaling $108.3 million associated with operating losses in Republic of the Congo and Suriname. The 2012 quarter also benefited from higher crude oil sales volumes and lower exploration expenses, but these were mostly offset by lower oil and natural gas sales prices and higher overall extraction and administrative expenses. The increase in extraction expenses in the current year was attributable to higher worldwide average crude oil production and higher depreciation unit rates in Malaysia associated with ongoing capital development activities.
|Three Mos. Ended||Years Ended|
|December 31,||December 31,|
|Oil Production Volume – Bbls. per day||132,918||108,771||112,591||103,160|
|Natural Gas Sales Volume – MCF per day||473,487||487,991||490,124||457,365|
|Total BOE Production Volume – BOE per day||211,833||190,103||194,278||179,388|
|Average Realized Oil Sales Price – $ per Bbl.||$||92.82||96.67||95.58||94.18|
Average Realized North American Natural Gas Sales Price – $ per MCF
Average Realized Sarawak Natural Gas Sales Price – $ per MCF
Exploration expenses totaled $137.2 million in the fourth quarter 2012, down from $185.6 million in the 2011 quarter. The decrease was primarily attributable to lower dry hole costs associated with unsuccessful exploratory drilling in the 2012 quarter in Canada and Brunei, partially offset by higher dry hole costs in the current quarter in Republic of the Congo.
Additionally, the 2012 quarter had lower leasehold amortization expense in the Kurdistan region of Iraq compared to the prior year.
Worldwide production totaled 211,833 barrels of oil equivalent per day in the 2012 fourth quarter, an 11% increase from the 190,103 barrels of oil equivalent per day produced in the 2011 quarter. Crude oil, condensate and gas liquids production was 132,918 barrels per day in the 2012 quarter compared to 108,771 barrels per day in 2011. The oil production increase in the current year was primarily attributable to an ongoing development drilling program in the Eagle Ford Shale area of South Texas as well as purchase of additional working interests in the Thunder Hawk and Front Runner fields in the Gulf of Mexico during 2012. Natural gas sales volumes averaged 473 million cubic feet per day in quarter four 2012, down 3% from the 488 million cubic feet per day sold in the prior year’s quarter. The 2012 reduction was primarily attributable to lower gas volumes produced at the Tupper area in Western Canada due to a planned shut-in of certain wells and virtually no development drilling in this area in the 2012 quarter because of continued weak North American natural gas sales prices. Natural gas production in 2012 in the U.S. was above 2011 levels primarily due to the development drilling program in the Eagle Ford Shale.
The average sales price for the Company’s crude oil, condensate and gas liquids was $92.82 per barrel for continuing operations in the 2012 fourth quarter, down from $96.67 per barrel in the 2011 quarter. Natural gas sales prices in North America averaged $3.34 per thousand cubic feet (MCF) in the 2012 quarter, down from $3.67 per MCF in the 2011 quarter. Natural gas sold from fields offshore Sarawak, Malaysia, averaged $6.78 per MCF in the 2012 quarter compared to $7.85 per MCF a year ago.
Refining and Marketing (R&M)
The Company’s refining and marketing business generated a quarterly profit from continuing operations of $38.5 million in the fourth quarter 2012 compared to a profit of $61.0 million in the same quarter a year earlier. U.S. R&M continuing operations generated earnings of $22.0 million in the fourth quarter of 2012 compared to earnings of $50.7 million in the 2011 quarter. The earnings reduction for this business in 2012 was principally the result of an impairment charge of $39.6 million after taxes to reduce the carrying value of the Hereford, Texas ethanol plant. The Company’s U.S. ethanol plants experienced weaker operating results in the 2012 quarter compared to the prior year due to depressed ethanol crush spreads. U.S. retail marketing operations reflected improved results as margins for this business averaged 14.1 cents per gallon in the 2012 quarter compared to 13.0 cents per gallon in the 2011 quarter. Retail operations also benefited from improved merchandise margins in the current quarter compared to a year ago. The U.K. R&M operations posted a net profit of $16.5 million in the 2012 quarter compared to a profit of $10.3 million in 2011, with the improved results based on better overall unit margins for this business.
|Three Mos. Ended||Years Ended|
|December 31||December 31|
|U.S. Retail Fuel Margins – Per gallon||$||0.141||0.130||0.129||0.156|
|U.S. Retail Merchandise sales per store month||$||154,730||157,425||156,429||158,144|
|U.K. Refinery Inputs – Bbls. per day||133,599||138,492||132,613||135,391|
|U.K. R&M Unit Margins – Per Bbl.||$||2.21||1.38||1.94||(0.67||)|
|Total Petroleum and Other Product Sales –|
|Bbls. per day*||494,406||465,946||474,949||556,434|
|*Includes 122,361 bbls. per day in the 2011 year related to discontinued operations.|
Corporate activities incurred after-tax costs of $21.1 million in the fourth quarter of 2012, well below the net costs of $34.3 million in the 2011 quarter. The 2012 cost reduction was primarily related to favorable effects from transactions denominated in foreign currencies. The 2012 quarter included an after-tax benefit of $3.5 million from foreign currencies, compared to an after-tax charge of $11.6 million in the 2011 quarter. The Company also had lower net interest expense in the 2012 quarter due to capitalizing a larger portion of its financing costs to oil development projects in the current period. Administrative expenses were higher in the 2012 quarter compared to a year earlier due to additional costs for professional services and employee compensation.
The loss from discontinued operations was $3.7 million ($0.02 per diluted share) in the fourth quarter 2012, compared to income of $4.0 million ($0.02 per diluted share) in the 2011 fourth quarter. The 2012 quarterly results included income tax adjustments related to the Company’s former U.S. oil refineries which were sold in 2011, mostly offset by profits from U.K. oil and gas production operations. The quarterly profit a year ago was primarily attributable to results of the U.K. oil and gas production operations. The sale of these U.K. oil and gas assets is expected to be completed during the first quarter 2013.
Year 2012 vs. Year 2011
Exploration and Production (E&P)
The Company’s E&P continuing operations earned $905.0 million for the full year 2012 compared to $614.2 million in 2011. The improvement in 2012 earnings versus 2011 was primarily attributable to higher oil production and lower impairment and exploration expenses in 2012, plus income tax benefits recognized in the current year related to U.S. tax deductions for losses incurred in Republic of the Congo and Suriname. The current year also benefited from marginally higher average crude oil sales prices. The 2011 period included a $13.1 million after-tax gain on sale of gas storage assets in Spain. Unfavorable effects in 2012 included lower North American natural gas sales prices and higher extraction expenses, with the latter caused by increased production levels and higher overall per-unit depreciation rates.
Total exploration expense was $380.9 million in 2012, down from $489.4 million in 2011. Exploration costs were lower in the current year due to more drilling success in 2012, plus lower geophysical expense in the Gulf of Mexico, Malaysia, Brunei and the Kurdistan region of Iraq.
Total worldwide production in 2012 was 194,278 barrels of oil equivalent per day, an 8% increase from 179,388 barrel equivalents produced in 2011. Total crude oil, condensate and gas liquids production averaged 112,591 barrels per day in 2012, an increase of 9% compared to the 2011 level of 103,160 barrels per day. The increase in the current year was mostly attributable to higher production in the Eagle Ford Shale area of South Texas and at the Kikeh field, offshore Sabah, Malaysia. Natural gas sales volumes increased from 457 million cubic feet per day in 2011 to 490 million cubic feet per day in 2012. The 7% increase in gas volumes in the current year was primarily attributable to higher production in the Tupper area and the Eagle Ford Shale. Natural gas volumes would have increased more in 2012 but for the fact that the Company voluntarily shut-in certain wells and significantly reduced development drilling in Western Canada due to depressed North American natural gas sales prices.
The average sales price for crude oil and other liquids for continuing operations was $95.58 per barrel in 2012 compared to $94.18 per barrel in 2011. North American natural gas was sold at an average price of $2.65 per MCF in 2012, significantly below the 2011 average of $4.08 per MCF. However, natural gas volumes produced offshore Sarawak were sold for $7.50 per MCF in 2012, up from $7.10 per MCF in the prior year.
Refining and Marketing (R&M)
The Company’s refining and marketing continuing operations generated a profit of $157.6 million in the year of 2012 compared to a profit of $190.3 million in 2011. U.S. R&M profits from continuing operations were $105.4 million in 2012 compared to $223.6 million in 2011. Operating results in 2012 for the U.S. R&M business were lower than 2011 due to weaker retail marketing margins and significantly lower margins for ethanol production operations. Per gallon margins for U.S. retail operations averaged 12.9 cents in 2012 compared to 15.6 cents in 2011. Ethanol production operating results were adversely affected by both weaker crush spreads and a $39.6 million after-tax asset impairment charge related to the Hereford, Texas plant. The U.K. R&M business produced a net profit of $52.2 million in 2012 compared to a net loss of $33.3 million in 2011. The improvement in U.K. operating results was attributable to more than a $2.60 per barrel increase in unit margins in the current year.
Corporate after-tax costs were $98.5 million in the year of 2012 compared to costs of $75.0 million in 2011. The significant unfavorable variance in 2012 compared to the prior year was mostly associated with foreign currency effects. Although after-tax effects from transactions denominated in foreign currencies were minimal in 2012, the prior year benefited from an after-tax gain of $20.7 million. The 2012 period also had higher administrative costs compared to 2011, primarily associated with more employee compensation and professional service expenses in the later period. However, net interest expense was lower in 2012 than 2011 essentially due to higher levels of interest capitalized to oil development projects in the current year.
Income from discontinued operations was $6.8 million in 2012 compared to $143.2 million in 2011. The 2011 results primarily related to income for two U.S. refineries sold in late 2011, including $113.1 million of operating profits and an $18.7 million net gain on disposal. Income from discontinued operations in both years included operating profits for U.K. offshore oil and gas assets that are expected to be sold in the first quarter 2013.
Steven A. Cossé, President and Chief Executive Officer, commented, “The just completed 2012 was an important year for our Company. Murphy’s Board decided to separate our U.S. downstream subsidiary into an independent public company; the completion of this process is expected during 2013. The U.S. retail business executed a new contract with Walmart, which will provide growth opportunities for this company for the next several years. In the oil and gas business, once again our reserves replacement significantly exceeded our oil and gas production volumes. We continued growth in our Eagle Ford Shale operation, where total production averaged 15,000 net barrels of oil equivalent per day for 2012, with expected 2013 annual production increasing to 30,000 net barrel equivalents per day. We added acreage and working interests in Canada and the Gulf of Mexico, while finalizing sale agreements for our oil and gas properties in the U.K. that are expected to close in the first quarter of this year. We also paid a $2.50 per share special dividend and commenced a stock buyback program near year-end.
“We anticipate total worldwide production volumes of 200,000 barrels of oil equivalent per day in the first quarter of 2013. Sales volumes of oil and natural gas are projected to average 202,000 barrels of oil equivalent per day during the quarter. At the present time, we expect income from continuing operations in the first quarter to range between $0.55 and $0.90 per diluted share. The first quarter estimate includes projected exploration expense of between $70 million and $140 million, and a loss from our downstream businesses of approximately $10 million. Results could vary based on the risk factors described below.”
The public is invited to access the Company’s conference call to discuss fourth quarter 2012 results on Thursday, January 31 at 12:00 p.m. CST either via the Internet through the Investor Relations section of Murphy Oil’s Web site at http://www.murphyoilcorp.com/ir or via the telephone by dialing 1-888-503-8172. The telephone reservation number for the call is 6962469. Replays of the call will be available through the same address on Murphy Oil’s Web site, and a recording of the call will be available through February 4 by calling 1-888-203-1112 and referencing reservation number 6962469. Audio downloads will also be available on the Murphy Web site through March 1 and via Thomson StreetEvents for their service subscribers.
This press release contains forward-looking statements as defined in the Private Securities Litigation Reform Act of 1995. These statements, which express management’s current views concerning future events or results, including Murphy’s plans to separate its U.S. downstream business and to divest its U.K. downstream and U.K. upstream operations, are subject to inherent risks and uncertainties. Factors that could cause one or more of these forecasted events not to occur include, but are not limited to, a failure to obtain necessary regulatory approvals, a failure to obtain assurances of anticipated tax treatment, a deterioration in the business or prospects of Murphy or its U.S. downstream business, adverse developments in Murphy or its U.S. downstream operation’s markets, adverse developments in the U.S. or global capital markets, credit markets or economies generally or a failure to execute a sale of the U.K. downstream or U.K. upstream operations on acceptable terms or in the timeframe contemplated. Factors that could cause actual results to differ materially from those expressed or implied in our forward-looking statements include, but are not limited to, the volatility and level of crude oil and natural gas prices, the level and success rate of our exploration programs, our ability to maintain production rates and replace reserves, customer demand for our products, adverse foreign exchange movements, political and regulatory instability, and uncontrollable natural hazards. For further discussion of risk factors, see Murphy’s 2011 Annual Report on Form 10-K and the September 30, 2012 Quarterly Report on Form 10-Q on file with the U.S. Securities and Exchange Commission. Murphy undertakes no duty to publicly update or revise any forward-looking statements.
MURPHY OIL CORPORATION
CONSOLIDATED FINANCIAL DATA SUMMARY
|Income (loss) from continuing operations||$||162,391,000||(117,953,000||)|
|Net income (loss)||$||158,687,000||(113,928,000||)|
Income (loss) from continuing operations per Common share
|Net income (loss) per Common share|
|Average shares outstanding|
|Income from continuing operations||$||964,046,000||729,471,000|
Income from continuing operations per Common share
|Net income per Common share|
|Average shares outstanding|
|*Reclassified to conform to current presentation.|