EL DORADO, Ark.--(BUSINESS WIRE)--Murphy Oil Corporation (NYSE: MUR) announced today that net income was $402.6 million ($2.12 per diluted share) in the 2013 second quarter, up from $295.4 million ($1.52 per diluted share) in the second quarter 2012. Net income in the 2013 quarter included income from discontinued operations of $70.5 million ($0.37 per diluted share) compared to income from discontinued operations of $4.1 million ($0.02 per diluted share) in the 2012 quarter. The 2013 income from discontinued operations was primarily generated by an after-tax gain of $71.9 million from sale of the Mungo and Monan fields in the United Kingdom during the just completed quarter. Income from continuing operations was $332.1 million ($1.75 per diluted share) for the 2013 second quarter compared to $291.3 million ($1.50 per diluted share) in the same quarter of 2012. The results of continuing operations improved in 2013 primarily due to higher earnings in the U.S. oil and gas business, which was attributable to growth in oil production in the Eagle Ford Shale area in South Texas.
For the first six months of 2013, net income was $763.2 million ($4.00 per diluted share), an improvement from $585.5 million ($3.01 per diluted share) in the similar 2012 period. Income from continuing operations for the six-month period of 2013 amounted to $540.1 million ($2.83 per diluted share), compared to income from continuing operations of $572.7 million ($2.94 per diluted share) in 2012. Income from discontinued operations of $223.1 million ($1.17 per diluted share) in the first six months of 2013 included a total gain after income taxes of $216.8 million from sale of all oil and gas properties in the United Kingdom.
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Net Income |
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| Three Mos. Ended | Six Mos. Ended | ||||||||||||||||
| June 30 | June 30 | ||||||||||||||||
| 2013 | 2012 | 2013 | 2012 | ||||||||||||||
| (Millions of Dollars) | |||||||||||||||||
| Exploration and Production | $ | 290.2 | 226.0 | 522.1 | 538.9 | ||||||||||||
| Refining and Marketing | 72.2 | 80.5 | 97.5 | 76.3 | |||||||||||||
| Corporate | (30.3 | ) | (15.2 | ) | (79.5 | ) | (42.5 | ) | |||||||||
| Income from continuing operations | 332.1 | 291.3 | 540.1 | 572.7 | |||||||||||||
| Income from discontinued operations | 70.5 | 4.1 | 223.1 | 12.8 | |||||||||||||
| Net income | $ | 402.6 | 295.4 | 763.2 | 585.5 | ||||||||||||
| Income per Common share – Diluted: | |||||||||||||||||
| Income from continuing operations | $ | 1.75 | 1.50 | 2.83 | 2.94 | ||||||||||||
| Net income | $ | 2.12 | 1.52 | 4.00 | 3.01 | ||||||||||||
Second Quarter 2013 vs. Second Quarter 2012
Exploration and Production (E&P)
The Company’s income from E&P continuing operations was $290.2 million in the second quarter of 2013 compared to $226.0 million in the same quarter of 2012. Improved 2013 quarterly income was driven by higher oil sales volumes in North America. Additionally, North American natural gas sales prices were significantly higher than in 2012, but the Company’s average realized crude oil sales prices were lower in the U.S. and Malaysia in the 2013 quarter. Natural gas production volumes in Canada and Malaysia in 2013 were below the levels produced in 2012. Exploration expenses were $88.8 million in the second quarter of 2013 compared to $96.7 million in the same period of 2012. Undeveloped leasehold amortization cost was $29.8 million lower in the 2013 quarter, primarily due to less expense associated with Eagle Ford Shale leases in the current year. Dry hole expense was $6.7 million higher in the 2013 second quarter primarily due to unsuccessful drilling results at the Bassett West prospect in Block WA-408-P offshore Australia. Geophysical costs were $12.0 million higher in the 2013 quarter, primarily associated with seismic data acquired in Australia, Vietnam, Indonesia and Suriname. The 2013 quarter included a $21.6 million impairment charge to writedown the carrying value of producing wells at Kainai in Southern Alberta. The 2013 quarter also had higher depreciation expense, primarily due to the increase in oil and gas sales volumes.
Worldwide production averaged 207,401 barrels of oil equivalent per day in the second quarter 2013, compared to 188,575 barrels of oil equivalent per day in the same quarter in 2012. Total crude oil and gas liquids production was 135,517 barrels per day in the 2013 quarter compared to 104,012 barrels per day in 2012. The increase in oil production in 2013 was primarily attributable to higher production in the Eagle Ford Shale area, where significant development drilling and completion operations are ongoing. Oil production at Syncrude in Western Canada also increased in the 2013 quarter due to less downtime for equipment maintenance. Crude oil production in the Seal heavy oil area of Western Canada was higher in the 2013 quarter primarily due to production from land acquired in the fourth quarter of 2012. The Azurite field, offshore Republic of the Congo, had lower crude oil production in 2013 due to well decline. Crude oil and gas liquids sales volumes averaged 137,106 barrels per day in the second quarter of 2013 compared to 104,768 barrels per day in the 2012 quarter. Natural gas sales volumes averaged 431 million cubic feet per day in the second quarter of 2013 compared to 507 million cubic feet per day in the 2012 quarter. Lower natural gas sales volumes in 2013 were primarily attributable to the effects of deferred development drilling operations in the Tupper area in British Columbia, Canada. Natural gas volumes sold at fields offshore Sarawak Malaysia was also down in the 2013 quarter due to lower customer demand caused by performance issues at the third party receiving facility and a lower percentage production entitlement allocable to the Company under the production sharing contract. The Company’s worldwide crude oil and gas liquids sales prices averaged $91.50 per barrel for the second quarter of 2013 down from $94.33 per barrel in the second quarter 2012. North American natural gas sales prices averaged $3.63 per thousand cubic feet (MCF) in the 2013 quarter, well above the $2.15 per MCF average in the same quarter of 2012. Natural gas produced offshore Sarawak, Malaysia was sold at an average realized price of $6.98 per MCF during the second quarter 2013 compared to $7.88 per MCF in 2012.
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E&P Metrics |
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| Three Mos. Ended | Six Mos. Ended | ||||||||||||
| June 30 | June 30 | ||||||||||||
| 2013 | 2012 | 2013 | 2012 | ||||||||||
| Oil Production Volume – Bbls. per day | 135,517 | 104,012 | 131,226 | 105,751 | |||||||||
| Natural Gas Sales Volume – MCF per day | 431,302 | 507,379 | 440,562 | 516,507 | |||||||||
| Total BOE Production Volume – BOE per day | 207,401 | 188,575 | 204,653 | 191,836 | |||||||||
| Average Realized Oil Sales Price – Per Bbl. | $ | 91.50 | 94.33 | 93.57 | 97.21 | ||||||||
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Average Realized North American Gas Sales Price – Per MCF |
$ | 3.63 | 2.15 | 3.36 | 2.36 | ||||||||
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Average Realized Sarawak Gas Sales Price – Per MCF |
$ | 6.98 | 7.88 | 7.03 | 7.80 | ||||||||
Refining and Marketing (R&M)
The Company previously announced its intent to sell its U.K. R&M assets. Ongoing sale activities related to these assets continue. The Company has also announced that it plans to separate its U.S. downstream business into a stand-alone, public company during 2013.
The Company’s refining and marketing operations generated income from continuing operations of $72.2 million in the second quarter 2013 compared to $80.5 million in the same quarter of 2012. The R&M earnings reduction in the 2013 second quarter was primarily attributable to weaker results in the United Kingdom, with a quarterly loss of $5.7 million in 2013 compared to a profit of $7.2 million in 2012.
U.S. income of $77.9 million in the 2013 quarter was above the 2012 quarterly income of $73.3 million, primarily due to better results for ethanol production operations and higher sales prices for ethanol renewable identification numbers (RINs) in the current period. The ethanol production facilities generated profitable results in the current quarter, following losses in the 2012 quarter. RINs were sold in the 2013 quarter at an average price of $0.78 per credit, compared to $0.02 per credit in the same quarter of 2012. U.S. retail marketing margins averaged $0.156 per gallon in the 2013 quarter compared to $0.197 per gallon in 2012. Fuel sales volume per store in the 2013 quarter was 1.2% above 2012 levels. Merchandise sales per store month were down 0.9% in the 2013 quarter compared to the prior year, while the percentage margin on merchandise sales was about 4.5% lower primarily caused by lower markups on certain tobacco products compared to 2012.
The unfavorable result in the U.K. in 2013 compared to 2012 was primarily due to lower overall unit margins, which averaged negative $0.27 per barrel in the 2013 quarter, compared to a positive margin of $1.26 per barrel a year ago. The margin decline in 2013 was due to weaker refining margins at the Milford Haven, Wales refinery, although in contrast, marketing operations in the U.K. realized better margins in the 2013 quarter. The Milford Haven refinery processed 130,324 barrels of crude oil per day in the 2013 quarter, slightly above the quarterly throughput volume of 130,059 barrels per day during the 2012 quarter.
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R&M Metrics |
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| Three Mos. Ended | Six Mos. Ended | ||||||||||||||
| June 30 | June 30 | ||||||||||||||
| 2013 | 2012 | 2013 | 2012 | ||||||||||||
| U.S. Retail Fuel Margin – Per gallon | $ | 0.156 | 0.197 | 0.134 | 0.137 | ||||||||||
| U.S. Retail Merchandise Sales – Per store month | $ | 157,138 | 158,626 | 152,072 | 155,783 | ||||||||||
| U.K. Refinery Inputs – Bbls. per day | 133,220 | 133,158 | 124,542 | 131,954 | |||||||||||
| U.K. R&M Unit Margin – Per Bbl. | $ | (0.27 | ) | 1.26 | (0.16 | ) | 1.03 | ||||||||
| Total Petroleum Product Sales – Bbls. per day | 481,727 | 483,561 | 453,058 | 467,049 | |||||||||||
Corporate
Corporate functions incurred net costs of $30.3 million in the 2013 second quarter compared to net costs of $15.2 million in the 2012 second quarter. The increased costs in 2013 were primarily attributable to higher interest and administrative expenses. Net interest expense was up $13.0 million in 2013 primarily due to higher average levels of debt outstanding in the current quarter, but this impact was somewhat tempered by attributing more financing costs to ongoing oil development projects in the current quarter. Administrative costs increased in the 2013 quarter due to both higher overall employee compensation expense and professional services associated with the upcoming separation of the U.S. downstream business into a stand-alone, public company. The after-tax effects from transactions in foreign currencies were gains of $16.2 million and $10.7 million in the second quarters of 2013 and 2012, respectively.
Discontinued Operations
The Company sold all of its U.K. oil and gas properties during the first six months of 2013, and the results thereof have been reported as discontinued operations for all periods presented. Income from discontinued operations totaled $70.5 million in the 2013 quarter and primarily included an after-tax gain of $71.9 million on sale of the Mungo and Monan fields. Income for these discontinued operations was $4.1 million during the 2012 quarter.
First Six Months 2013 vs. First Six Months 2012
Exploration and Production (E&P)
The Company’s E&P business earned $522.1 million from continuing operations in the first six months of 2013 compared to earnings of $538.9 million in the same period of 2012. The 2013 results were below 2012 due to lower average realized sales prices for crude oil and Sarawak natural gas, plus higher exploration expenses. These were partially offset by very favorable oil sales volumes as well as improved North American natural gas sales prices in 2013. Natural gas sales volumes were lower in Canada and Malaysia during the 2013 period. Exploration expenses were $197.3 million in 2013, up from $149.7 million in 2012, with the higher costs in the current period primarily related to dry holes offshore Australia and in Southern Alberta in 2013. Additionally, the Company incurred higher expense in 2013 for seismic data acquisitions covering prospective areas in Indonesia, Australia and Cameroon. Production and depreciation expenses rose in 2013 compared to 2012 due to higher hydrocarbon sales volumes and higher unit costs per barrel of oil equivalent produced.
Worldwide production averaged 204,653 barrels of oil equivalents per day during the first six months of 2013 compared to 191,836 barrel equivalents per day in the same period a year ago. Crude oil and gas liquids production for the first six months of 2013 averaged 131,226 barrels per day compared to 105,751 barrels per day in 2012. The oil production increase in 2013 was mostly caused by higher crude oil volumes produced in the Eagle Ford Shale of South Texas. Additionally, crude oil production increased in Canada and Malaysia in the 2013 quarter due to higher production for heavy oil and start-up of the Kakap field, respectively. Oil sales volumes in the first six months of 2013 totaled 134,308 barrels per day compared to 106,665 barrels per day in 2012. Natural gas sales volumes were 440 million cubic feet per day in 2013 compared to 516 million cubic feet per day in 2012, with the reduction primarily resulting from voluntary deferral of development activities in the Tupper area in British Columbia. Natural gas production also declined in 2013 at fields offshore Sarawak primarily due to planned maintenance at the Company’s gas receiving facility and a lower entitlement allocation to the Company. Crude oil and gas liquids sales prices averaged $93.57 per barrel in the 2013 period compared to $97.21 per barrel in 2012. North American natural gas was sold at an average price of $3.36 per MCF in 2013, significantly higher than the $2.36 per MCF realized in 2012. Sales prices for Sarawak natural gas production averaged $7.03 per MCF during the first six months of 2013 compared to $7.80 per MCF during 2012.
Refining and Marketing (R&M)
The Company’s refining and marketing earnings were $97.5 million in the first six months of 2013, compared to earnings of $76.3 million in the same 2012 period. U.S. earnings were $107.3 million in the 2013 six months, up from $66.1 million in the 2012 period. The 2013 earnings improvement was primarily attributable to stronger ethanol results and a rise in the sales value of ethanol RINs compared to the prior year. Ethanol margins improved as average sales prices for the product increased more than corn feedstock prices in the current year. Also, the sales value of distillers’ grain was stronger in 2013 than in the prior year. Profit from ethanol RIN sales was higher in 2013 due to significantly stronger sales prices for these credits. U.S. retail marketing margins averaged $0.134 per gallon in the 2013 six-month period compared to $0.137 per gallon in the 2012 six months. Fuel sales per store month in 2013 were essentially flat compared to 2012, while merchandise sales revenue per store and merchandise margin as a percentage of sales were each down about 2% in 2013 compared to 2012.
R&M operations in the U.K. in the six-month 2013 period incurred a loss of $9.8 million compared to a profit of $10.2 million in the prior year, as the business experienced weaker margins at the Milford Haven, Wales, refinery in 2013. Improved margins for marketing operations in the current period partially offset the weaker refining results. Average U.K. unit margins were negative $0.16 per barrel in the first six months of 2013 compared to a positive margin of $1.03 per barrel in the 2012 period.
Corporate
Corporate after-tax costs were $79.5 million in the first six months of 2013 compared to after-tax costs of $42.5 million in the 2012 period. The increase in net costs was primarily attributable to higher net interest expense of $21.3 million in 2013 compared to 2012 principally caused by higher borrowing levels, which was partially offset by a higher proportion of financing costs being capitalized to ongoing oil development projects in the current period. Administrative expenses associated with corporate activities were higher in 2013 compared to the prior year due to additional costs for employee compensation as well as professional fees associated with the upcoming separation of the U.S. downstream business. The 2013 results included a $12.2 million after-tax gain on transactions denominated in foreign currencies compared to an after-tax gain of $9.1 million in 2012.
Discontinued Operations
Income from discontinued operations amounted to $223.1 million in the first six months of 2013, up from $12.8 million in the same period of 2012. The significant increase in 2013 income compared to the prior year was primarily attributable to $216.2 million of after-tax gains on sale of all U.K. oil and gas properties in 2013.
Steven A. Cossé, President and Chief Executive Officer, commented, “Our oil production levels held up well during the second quarter, but will retract a bit in quarter three primarily due to planned downtime at Kikeh for tie-in of the Siakap North field. At the end of the second quarter, we started up crude oil production at Serendah, the first of our four new oil fields offshore Sarawak. We expect the other three Sarawak fields to come on production with staggered start-ups during the second half of this year. We continued our portfolio rationalization in the second quarter as we completed the exit of the U.K. oil and gas business with the sale of the Mungo and Monan fields. Our exploration program continues with the Dufresne prospect well offshore Australia now drilling at intermediate depth.
“As to the planned spin-off of our U.S. downstream business, substantial progress has been made. We have announced the Murphy USA Inc. Board of Directors, and the management team and organization are in place and are up and running. We have received a ruling from the Internal Revenue Service confirming the tax-free status of the transaction and we are making good progress with our Securities and Exchange Commission filing. Murphy USA is in the process of finalizing its capital structure. We expect that the Murphy Oil Corporation Board of Directors will consider this progress at its meeting next Wednesday and we would expect to announce the Board’s conclusion shortly thereafter.
“We anticipate total worldwide production volumes of about 190,000 barrels of oil equivalent per day in the third quarter of 2013, with similar levels of sales volumes during this period. We now anticipate full year 2013 production volumes of 203,000 barrels of oil equivalent per day. Due to the transformation of Murphy Oil to a pure play E&P company with the anticipated spin-off of the U.S. retail business, we will no longer provide future quarterly earnings guidance in our earnings press release. Murphy Oil and Murphy USA are each considering the type of future quarterly guidance that will be provided going forward.”
The public is invited to access the Company’s conference call to discuss second quarter 2013 results on Thursday, August 1, at 12:00 p.m. CDT either via the Internet through the Investor Relations section of Murphy Oil’s Web site at http://www.murphyoilcorp.com/ir or via telephone by dialing 1-877-856-1968. The telephone reservation number for the call is 3576715. 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 August 5 by calling 1-888-203-1112 and using the same reservation number shown above. Audio downloads of the conference will be available on Murphy’s Web site through September 3 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. retail marketing business and to divest its U.K. downstream 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. retail marketing business, adverse developments in Murphy or its U.S. retail marketing business’ markets, adverse developments in the U.S. or global capital markets, credit markets or economies in general or a failure to execute a sale of the U.K. downstream 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 2012 Annual Report on Form 10-K on file with the U.S. Securities and Exchange Commission. Murphy undertakes no duty to publicly update or revise any forward-looking statements.
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MURPHY OIL CORPORATION CONSOLIDATED FINANCIAL DATA SUMMARY (Unaudited) |
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SECOND QUARTER |
2013 |
2012 |
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| Revenues | $ | 7,217,842,000 | $ | 7,157,605,000 | ||
| Income from continuing operations | $ | 332,128,000 | $ | 291,306,000 | ||
| Net income | $ | 402,644,000 | $ | 295,437,000 | ||
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Income from continuing operations per Common Share |
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| Basic | $ | 1.76 | $ | 1.50 | ||
| Diluted | $ | 1.75 | $ | 1.50 | ||
| Net income per Common share | ||||||
| Basic | $ | 2.13 | $ | 1.52 | ||
| Diluted | $ | 2.12 | $ | 1.52 | ||
| Average shares outstanding | ||||||
| Basic | 189,002,146 | 194,208,795 | ||||
| Diluted | 189,944,793 | 194,846,202 | ||||
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FIRST SIX MONTHS |
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| Revenues | $ | 13,857,796,000 | $ | 14,114,541,000 | ||
| Income from continuing operations | $ | 540,098,000 | $ | 572,744,000 | ||
| Net income | $ | 763,243,000 | $ | 585,508,000 | ||
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Income from continuing operations per Common share |
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| Basic | $ | 2.85 | $ | 2.95 | ||
| Diluted | $ | 2.83 | $ | 2.94 | ||
| Net income per Common share | ||||||
| Basic | $ | 4.02 | $ | 3.02 | ||
| Diluted | $ | 4.00 | $ | 3.01 | ||
| Average shares outstanding | ||||||
| Basic | 189,753,673 | 194,050,950 | ||||
| Diluted | 190,702,248 | 194,820,285 | ||||
