Marathon Oil Reports $3.87B in 2Q11 Revenue

Marathon Oil reported second quarter 2011 net income of $996 million, or $1.39 per diluted share. Net income in the second quarter of 2010 was $709 million, or $1.00 per diluted share. On June 30, 2011, Marathon Oil completed the spin-off of its Refining, Marketing and Transportation business, now reported as discontinued operations and excluded from segment income; as a result, income from continuing operations will be best suited for comparison. For the second quarter of 2011, adjusted income from continuing operations was $689 million, or $0.96 per diluted share, compared to adjusted income from continuing operations of $440 million, or $0.62 per diluted share, for the second quarter 2010. Second quarter revenue in 2011 was $3.87 billion, compared to $2.9 billion in 2010.

"In the second quarter we successfully completed the spin-off of our downstream business and announced the pending $3.5 billion acquisition of assets in the Eagle Ford shale in Texas," said Clarence P. Cazalot Jr., Marathon Oil's chairman, president and CEO. "Our second quarter financial results, while solid, were negatively impacted by unplanned downtime at key international operations which held our second quarter production to the lower end of guidance. These operations are all back operating at or above expected capacity. 

"Importantly, our production forecast and capital expenditure guidance for 2011, excluding acquisitions, remain unchanged. Going forward, we are confident that we have the foundation in place to deliver 5 to 7 percent compound average production growth during the period 2010 - 2016. This strong growth profile is underpinned by our pending top-five acreage position in the core, liquids-rich area of the Eagle Ford, as well as solid positions across the Bakken, Anadarko Woodford and Niobrara liquids-rich resource plays. 

"In the Bakken alone we have increased our production growth target and now expect to average 33,000 net barrels of oil equivalent per day (boepd) by 2016. With our plans to significantly increase rig activity to more than 40 rigs over the next 18 months, we see approximately 175,000 boepd of net production across our substantial North America unconventional portfolio by 2016. Additionally, we expect our strong base assets to deliver the cash flow and earnings to fund this growth while we continue to maintain a solid balance sheet and competitive dividend," Cazalot said. 

Segment Results

Total segment income was $713 million in the second quarter of 2011, compared to $396 million from continuing operations in the second quarter of 2010.

Exploration and Production

Exploration and Production (E&P) segment income totaled $601 million in the second quarter of 2011, compared to $432 million in the year-ago quarter. The increase was primarily the result of higher liquid hydrocarbon price realizations, partially offset by decreased sales volumes in Libya and Europe and increased depreciation, depletion and amortization (DD&A). Excluding Libya, Marathon Oil was underlifted by 333,000 barrels of oil equivalent (boe) in the second quarter compared to a 1,217,000 boe overlift in the same quarter last year. There was minimal derivatives impact in the second quarter of 2011, while a pre-tax gain of $29 million was included in results for the second quarter of 2010. 

E&P production available for sale for the second quarter of 2011 averaged 341,000 boepd, of which 59 percent was liquid hydrocarbons (202,000 barrels per day) and 41 percent was natural gas (833 million cubic feet per day of natural gas). Production was at the low end of guidance largely because of unplanned downtime in Norway, where the Alvheim floating production, storage and offloading (FPSO) vessel was off-line for 13 days to ensure the safe operation of the fire protection system, and to a lesser extent in Equatorial Guinea. Second quarter 2010 production available for sale was 328,000 boepd (excluding 47,000 boepd from Libya). 

Marathon Oil estimates third quarter E&P production available for sale will be between 330,000 and 350,000 boepd, which reflects planned maintenance activities in both operated and non-operated assets in the U.K., and includes potential hurricane effects in the Gulf of Mexico. While the mid-point remains unchanged, the range of anticipated full-year E&P production available for sale has been narrowed to between 350,000 and 360,000 boepd, which includes an average 7,000 boepd from Libya. For the E&P segment, Marathon Oil anticipates producing on average 360,000 - 380,000 boepd in 2012, which, due to the uncertain timing of a restart to production from the Company's Libya assets, excludes any Libya production, and excludes the effect of acquisitions or dispositions not previously announced. 

E&P sales volumes during the second quarter of 2011 averaged 337,000 boepd, compared to sales volumes of 342,000 boepd (excluding 44,000 boepd from Libya) for the same period in 2010. The slightly lower sales volumes were primarily the result of the timing of liftings from the U.K. and the previously discussed international downtime. 

United States E&P reported income of $126 million for the second quarter of 2011, compared to $25 million in the second quarter of 2010. The increase was the result of higher liquid hydrocarbon realizations and sales volumes in the Gulf of Mexico, partly offset by increased DD&A. 

International E&P income was $475 million in the second quarter of 2011, compared to $407 million in the second quarter of 2010. The increase reflects the impact of higher liquid hydrocarbon realizations, partially offset by lower sales volumes in Libya, the U.K. and Norway. 

Exploration expenses were $145 million for the second quarter of 2011, including $62 million of dry well costs, compared to $125 million in the second quarter of 2010, which included $57 million in dry wells. Dry well costs during the second quarter of 2011 included $38 million related to the Earb exploration well in the Norwegian North Sea, and $22 million incurred subsequent to the first quarter of 2011 related to the Romeo well in the Pasangkayu block offshore Indonesia.

EAGLE FORD: On Marathon Oil's existing acreage, four wells have been drilled and are being tested. During the second quarter, Marathon Oil announced an agreement to acquire Eagle Ford shale assets in south Texas for $3.5 billion, subject to closing adjustments. The transaction is expected to close Nov. 1 with an effective date of May 1. Including this transaction, Marathon Oil's 2011 exit rate from the Eagle Ford is expected to exceed 13,000 net boepd. 

BAKKEN: Marathon Oil has seven rigs currently operating in the Bakken in North Dakota, with current production of 16,000 net boepd. Production is expected to increase substantially in the second half of the year as the Company adds a second crew for hydraulic fracturing activities. The Company has 28 gross operated wells awaiting stimulation and plans to fracture stimulate 50 total wells before the end of the year. The Company now expects to exit 2011 with production at approximately 20,000 net boepd, and to reach 33,000 net boepd by 2016. 

ANADARKO WOODFORD: Marathon Oil has ramped up to five rigs currently drilling in the Anadarko Woodford in Oklahoma, and expects to have eight rigs operating by the end of the year. The Company is currently producing less than 2,000 net boepd and plans to end the year with production of approximately 5,000 net boepd. 

OTHER NORTH AMERICA ONSHORE: In the Niobrara Shale play within the DJ Basin of southeast Wyoming and northern Colorado, results have been positive from two vertical wells drilled. The Company spud its first horizontal exploration well in early July, and expects to add a second rig by September 2011. Marathon Oil continues to acquire seismic data and plans to drill eight to twelve gross wells by year end. The Company also progressed concept selection in its Birchwood in situ project in Alberta, Canada, and anticipates reaching a final investment decision on the first stage of the project in 2012. 

GULF OF MEXICO: Marathon Oil has submitted plans to resume drilling on the Innsbruck prospect (Mississippi Canyon Block 993, 85 percent working interest and operator) and is awaiting regulatory approval. In accordance with the federal government's drilling moratorium, drilling on the Innsbruck prospect was suspended in the second quarter of 2010 at a depth of 19,800 feet as compared to a proposed total depth of 29,500 feet. Additionally, due to operator issues at the non-operated host platform, first production from Ozona (Garden Banks block 515) has been delayed until year end. Marathon Oil is completing the well as a single zone oil producer, and expects a 2012 production rate of more than 9,000 net boepd, of which approximately 80 percent is oil. Overall reserve estimates and project costs have remained consistent since project sanctioning. Marathon Oil holds a 68 percent working interest in the Ozona Field, and serves as operator. 

POLAND: In late July, Marathon Oil closed a transaction in which Mitsui & Co. acquired a 9 percent working interest in 10 of Marathon Oil's shale gas concessions in Poland. This transaction provides further financial risk mitigation and aligns the Company with another strong partner as Marathon Oil, Mitsui and Nexen prepare to explore and evaluate the full potential of these concessions. Marathon Oil holds a 51 percent working interest in these 10 concessions and serves as operator. The Company plans to spud two wells in the country in 2011. 

IRAQI KURDISTAN REGION: Marathon Oil participated in its second discovery in the Iraqi Kurdistan Region during the second quarter. The Swara Tika-1 discovery on the Sarsang block was drilled to a total depth of approximately 12,500 feet and encountered 1,500 feet of gross oil column. Flow rates were established from three zones totaling more than 7,000 barrels of light oil per day (bopd) with associated gas. The flow rates were limited by tubing sizes and testing equipment. Marathon Oil holds a 25 percent working interest in the Sarsang block.

Oil Sands Mining

The Oil Sands Mining (OSM) segment reported income of $69 million for the second quarter of 2011, compared to a loss of $60 million in the second quarter of 2010. A pre-tax gain of $53 million on derivatives was included in results for the second quarter of 2010, but there were no derivative impacts in the second quarter of 2011. The increase in segment income was primarily the result of higher synthetic crude oil sales volumes and higher price realizations as compared to the same quarter last year. Current operating expense per synthetic barrel (before royalties) is $46, compared to $54 in the first quarter of 2011, with the partners continuing to focus on reducing the per barrel cost as production increases for this very long-life asset. 

The Jackpine Mine commenced a phased start-up in the third quarter of 2010, and the expanded Scotford upgrader came on line in the second quarter of 2011, increasing overall production. Marathon Oil's second quarter 2011 net synthetic crude production (upgraded bitumen excluding blendstocks) from the Athabasca Oil Sands Project (AOSP) mining operation was 37,000 barrels per day (bpd). This compares to the same period in 2010 when the AOSP produced 15,000 bpd. The Scotford upgrader achieved full capacity in June. Marathon Oil holds a 20 percent working interest in the AOSP.

Marathon Oil expects third quarter net synthetic crude production will be between 40,000 and 45,000 bpd, with anticipated full-year 2011 net synthetic crude production unchanged at between 39,000 and 45,000 bpd. Marathon Oil anticipates producing on average 40,000 to 50,000 bpd of synthetic crude in 2012. Reliable operating performance by the operator is critical to achieving these targets. 

In the second quarter of 2011, as a result of life extension for the Greater Jackpine Area, and in accordance with the terms of the original 1999 AOSP Joint Venture Agreement, Shell transferred to Marathon Oil a 20 percent ownership of the portion of Lease 13 known as the Greater Jackpine Area. Marathon Oil has increased net proved developed reserves by approximately 54 million barrels.

Integrated Gas

Integrated Gas segment income was $43 million in the second quarter of 2011, compared to $24 million in the second quarter of 2010. While segment income continued to be affected by weak Henry Hub gas prices, the increase was primarily related to higher volumes. The liquefied natural gas (LNG) facility in Equatorial Guinea had operational availability of 95 percent for the second quarter, which included the impact of a scheduled turnaround.

Special Items/Corporate

During the second quarter of 2011, Marathon Oil assigned an undivided 30 percent working interest in 180,000 acres in the Niobrara Shale play, located in southeast Wyoming and northern Colorado, to another company for $270 million, recording a gain of $24 million net of tax ($39 million pretax). 

In May 2011, significant water production increases and reservoir pressure declines occurred at the Droshky development. Plans for a waterflood have been cancelled and the field will be produced to abandonment pressures, expected in the first half of 2012. Consequently, 3.4 million boe of proved reserves were written off and a $178 million net of tax ($273 million pretax) long-lived asset impairment was recorded in the second quarter of 2011. 

Marathon Oil's outlook for future U.S. LNG imports makes it unlikely that sufficient U.S. demand for LNG will materialize by 2021, when the rights lapse under arrangements at the Elba Island, Georgia, LNG regasification facility. As a result, Marathon Oil recorded a special item of $17 million net of tax ($25 million pretax) for the full impairment of this intangible asset in the second quarter of 2011. 

During the second quarter, the AOSP operator determined the need for and developed preliminary plans to address water flow into a previously mined and contained section of the Muskeg River mine. Estimated costs of $48 million net of tax ($64 million pretax) net to Marathon Oil have been recorded in the second quarter of 2011. 

Related to activity of the Company's former downstream business, which is now included in discontinued operations, income tax expense increased due to the impact of state tax law changes and state valuation allowance adjustments. Net of federal tax, $50 million was recorded in the second quarter of 2011. 

Related to the tax effect of restructuring international subsidiaries, Marathon Oil recorded a one-time non-cash tax expense of $122 million in the second quarter of 2011. 

Marathon Oil's 2011 capital, investment and exploration budget remains unchanged and is expected to be $3.9 billion, excluding discontinued operations, asset acquisitions and associated development capital. This includes approximately $3.4 billion for worldwide E&P, approximately $300 million for Oil Sands Mining, and approximately $200 million for the corporate budget including capitalized interest. Asset acquisitions announced to date, along with associated 2011 development capital, are expected to be approximately $4 billion.

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