HOUSTON, Aug. 3 /PRNewswire-FirstCall/ -- Marathon Oil Corporation (NYSE: MRO) today reported second quarter 2009 net income of $413 million, or $0.58 per diluted share. Net income in the second quarter 2008 was $774 million, or $1.08 per diluted share. For the second quarter 2009, adjusted net income was $251 million, or $0.35 per diluted share, compared to adjusted net income of $858 million, or $1.20 per diluted share, for the second quarter of 2008.
Three Months
Ended
June 30
(In millions, except per diluted share data) 2009 2008 (b)
-------------------------------------------- ---- --------
Adjusted net income (a) $251 $858
Adjustments for special items (net of taxes):
Gain (loss) on U.K. natural gas contracts 2 (84)
Gain on disposal of assets 160 -
--- ---
Net income $413 $774
---------- ---- ----
Adjusted net income (a) - per diluted share $0.35 $1.20
Net Income - per diluted share $0.58 $1.08
Revenues and other income $13,358 $22,202
Weighted average shares - diluted 711 714
---------------------------------- --- ---
(a) Adjusted net income is a non-GAAP financial measure and should not
be considered a substitute for net income as determined in
accordance with accounting principles generally accepted in the
United States. See below for further discussion of adjusted net
income.
(b) Previously reported revenues and other income have been revised to
reflect the presentation of Marathon's Irish businesses as
discontinued operations.
"Marathon's businesses performed very well in the second quarter. Our Exploration and Production segment achieved a 12 percent year-over-year increase in production available for sale from continuing operations while our Refining, Marketing and Transportation segment out-performed its competitors in the domestic market posting positive financial results, up slightly from both first quarter and prior year," said Clarence P. Cazalot, Jr., president and CEO of Marathon. "A continued focus on high mechanical reliability and cost control contributed to our overall solid operating performance. And, in spite of challenging global economic conditions, Marathon continues to maintain a very solid financial position, aided by the value captured from selective asset sales."
Segment Results
Total segment income was $400 million in the second quarter of 2009, compared to $925 million in the second quarter of 2008.
Three Months
Ended
June 30
(In millions) 2009 2008(b)
------------- ---- -------
Segment Income (Loss)
Exploration and Production
United States $(41) $359
International 261 463
--- ---
Total E&P 220 822
Oil Sands Mining 2 (157)
Refining, Marketing and Transportation 165 158
Integrated Gas 13 102
-- ---
Segment Income (a) $400 $925
------------------ ---- ----
(a) See Preliminary Supplemental Statistics below for a reconciliation
of segment income to net income as reported under generally accepted
accounting principles.
(b) Previously reported Exploration and Production segment income has
been revised to reflect the presentation of Marathon's Irish
businesses as discontinued operations.
Exploration and Production
Exploration and Production (E&P) segment income totaled $220 million in the second quarter of 2009, compared to $822 million in the second quarter of 2008. The decrease was primarily a result of lower liquid hydrocarbon and natural gas price realizations.
Sales volumes from continuing operations increased 26 percent year on year, averaging 436,000 barrels of oil equivalent per day (boepd), compared to 347,000 boepd for the same period last year. While the increase in sales volumes is primarily due to the timing of international liftings, production available for sale from continuing operations in the quarter was up 12 percent to 411,000 boepd from the same quarter in 2008. Production increased with the addition of the Alvheim/Vilje development offshore Norway, which started operation in June 2008, and with increased natural gas sales volumes in Equatorial Guinea due to exceptional reliability at the LNG and methanol facilities on Bioko Island which purchase natural gas from the Company's Alba field, partially offset by lower United States natural gas production as investment activities have been curtailed due to lower natural gas prices.
International E&P income was $261 million in the second quarter of 2009, compared to $463 million in the second quarter of 2008. The decrease was primarily a result of lower liquid hydrocarbon price realizations in the second quarter 2009, partially offset by increased income from the Alvheim/Vilje development and improved operating reliability across the business, highlighted by operations at the Equatorial Guinea natural gas producing and processing facilities where reliability was 97.5 percent for the quarter. Additionally for the quarter, international E&P saw a 17 percent decline in per barrel operating costs [excluding depreciation, depletion and amortization (DD&A) and exploration expense], as costs fell to $6.22 per boe in the second quarter 2009 from $7.46 per boe in the comparable quarter of 2008 through stronger volume performance and increased focus on cost reduction initiatives. Lower exploration expenses also had a positive impact on results. The change in mix of product sales year-over-year included higher sales in jurisdictions with high tax rates. This change contributed to the higher segment effective tax rate for the quarter.
U.S. E&P reported a loss of $41 million in the second quarter of 2009, compared to income of $359 million in the second quarter of 2008, as revenues decreased by 60 percent, primarily the result of 52 percent lower liquid hydrocarbon and 58 percent lower natural gas price realizations. DD&A increased to $271 million during the second quarter 2009, up $100 million from the same period last year. The Neptune development, which started operation in July 2008, added $90 million of DD&A over the second quarter of 2008. Also contributing to the loss were pretax expenses totaling $28 million ($17 million after tax) recognized in the second quarter of 2009, primarily for partial impairment of a natural gas field in east Texas, as well as a rig cancellation in the Bakken and a loss on a sale. Pretax expenses during the first six months of 2009 from rig cancellations totaled $24 million, and the Company does not anticipate any additional cancellations for the remainder of the year. As a result of a capital expenditure program with more emphasis on oil projects, U.S. E&P reported a year-over-year increase in liquid hydrocarbon production volumes of approximately 1,000 barrels per day (bpd) for the second quarter and over 2,000 bpd for the first half of 2009.
Three Months
Ended
June 30
2009 2008
---- ----
Key E&P Production Statistics
Net Sales
United States - Liquids (mbpd) 64 63
United States - Natural Gas (mmcfpd) 365 431
International - Liquids (mbpd) 213 119
International - Natural Gas (mmcfpd) 590 558
Worldwide Net Sales from Continuing Operations (mboepd) 436 347
-------------------------------------------------------- --- ---
Marathon's Alvheim/Vilje development in Norway completed a planned 12-day turn-around in the second quarter of 2009, and still achieved strong operational performance for the quarter, with production available for sale averaging 69,800 net boepd [64,300 net bpd of liquid hydrocarbons and 32.6 million net cubic feet per day (mmcfpd) of natural gas]. Also in Norway, the Volund development is on schedule to be operationally ready for production in the fourth quarter of 2009. Importantly, due to better than expected production from the Alvheim field, the Volund start-up is not expected until the first half of 2010, subject to available processing capacity on the Alvheim floating, production, storage and offloading vessel. Marathon has 65 percent operated interests in Alvheim and Volund and a 47 percent outside-operated interest in Vilje.
The Company announced the Oberon discovery on Angola Block 31. Also in Angola, the PSVM development, located in the northeast sector of the block, is proceeding with first production targeted in 2012. In July 2009, Marathon entered into a definitive agreement to sell an undivided 20 percent participating interest in the Production Sharing Contract and Joint Operating Agreement in Angola Block 32. See the Corporate section below for further discussion of this transaction.
Marathon was awarded a 49 percent interest and will serve as operator in the Kumawa Block offshore Indonesia, which is Marathon's third Indonesian offshore exploration block. The Kumawa Block encompasses 1.24 million acres in a high-potential, under-explored area.
In the Gulf of Mexico, Marathon has completed drilling all four development wells on its Droshky project, located on Green Canyon Block 244, and well completions are underway. First production is targeted for 2010.
Oil Sands Mining
Oil Sands Mining (OSM) segment income was $2 million for the second quarter of 2009 compared to a loss of $157 million in the second quarter of 2008 that included a $250 million after-tax loss on derivative instruments. Excluding the derivative impact, income was adversely impacted by a 53 percent decrease in average realizations, partially offset by lower blendstock and energy costs.
Three Months
Ended
June 30
2009 2008
---- ----
Key Oil Sands Mining Statistics
Net Bitumen Production (mbpd) 26 24
Net Synthetic Crude Oil Sales (mbpd) 30 31
Synthetic Crude Oil Average Realization (per bbl)(a) $55.02 $116.40
---------------------------------------------------- ------ -------
(a) Excludes gains and losses on derivative instruments.
Marathon's second quarter 2009 net bitumen production from the Athabasca Oil Sands Project (AOSP) mining operation was 26,000 bpd, compared to 24,000 bpd in the same quarter of last year.
The AOSP Phase 1 expansion is on track and is anticipated to begin operations in the 2010/2011 timeframe. The Phase 1 expansion includes construction of mining and extraction facilities at the Jackpine mine, expansion of treatment facilities at the existing Muskeg River mine, expansion of the Scotford upgrader and development of related infrastructure.
In the second quarter, the operator of AOSP offered three additional leases to the joint venture partners as a life-of-mine extension for the Muskeg River mine. Terms of the transaction were as agreed in the original 1999 AOSP Joint Venture Agreement. Marathon elected to participate in these leases and was able to reclassify approximately 190 million net barrels of contingent resource. Net proved bitumen reserves increased approximately 168 million barrels and net probable bitumen reserves increased 22 million barrels. These additional reserve barrels resulted in reducing Marathon's OSM DD&A rate per barrel by approximately 40 percent, starting in June 2009.
Also during the second quarter, the Alberta Government announced its decision to consider AOSP's Quest carbon capture and storage (CCS) project, involving the Scotford base and Phase 1 expansion upgraders, for possible government funding. The AOSP partners are currently working with the government on a letter of intent, after which a funding agreement will be negotiated. A final investment decision on the Quest project will be made at a later date, pending agreement on funding details with the Government of Alberta, regulatory approvals, stakeholder engagement, as well as final joint venture partner agreement.
Refining, Marketing and Transportation
Refining, Marketing and Transportation (RM&T) segment income was $165 million in the second quarter of 2009 compared to $158 million in the second quarter of 2008. The second quarter 2009 refining and wholesale marketing gross margin of 8.71 cents per gallon increased slightly from 8.35 cents in the second quarter of 2008. The gross margin increase was primarily due to improved crack spreads as reflected in the relevant market indicators [Light Louisiana Sweet (LLS) 6-3-2-1 crack spreads] in the Midwest (Chicago) and Gulf Coast and lower manufacturing expenses in the second quarter 2009 compared to the same quarter last year. The lower manufacturing expenses resulted primarily from lower energy costs. However, these favorable impacts were largely offset by a relatively higher cost of crude oil, primarily driven by a substantially narrower sweet-sour differential, and other feedstock costs compared to the average prices reflected in the market indicators.
Marathon's second quarter 2009 refining and wholesale marketing gross margin included pretax derivative gains of $13 million, primarily resulting from management of crude oil inventory price risk exposure. The second quarter 2008 gross margin included pretax derivative losses of $187 million including the impact of using derivatives to mitigate domestic crude oil acquisition price risk, a practice that the Company discontinued during that quarter.
Crude oil refined during the second quarter of 2009 averaged 959,000 bpd, a 64,000 bpd decrease from the second quarter of 2008, and total refinery throughputs were 1,158,000 bpd, approximately 4 percent lower than the 1,203,000 bpd in the second quarter of 2008.
Three Months
Ended
June 30
2009 2008
---- ----
Key Refining, Marketing & Transportation
Statistics
Crude Oil Refined (mbpd) 959 1,023
Other Charge and Blend Stocks (mbpd) 199 180
--- ---
Total Refinery Inputs (mbpd) 1,158 1,203
Refined Products Sales Volumes (mbpd) 1,371 1,369
Refining and Wholesale Marketing Gross Margin ($/
gallon) $0.0871 $0.0835
------------------------------------------------- ------- -------
Speedway SuperAmerica LLC (SSA) gasoline and distillate gross margin per gallon averaged 10.51 cents in the second quarter of 2009, compared to 8.62 cents in the second quarter of 2008. SSA second quarter 2009 same store gasoline sales volume increased by approximately 3 percent over the second quarter of 2008 -- versus an estimated demand decline of about 2 percent in the Company's market area in the second quarter 2009 -- while same store merchandise sales increased by approximately 14 percent for the same period.
According to the 2009 EquiTrend((R)) Brand Study conducted by Harris Interactive, Speedway has been named the best brand in the nation in its respective category. This renowned, annual online study measures consumer brand familiarity, quality, distinctness, trust and other criteria.
At July 31, the Garyville Major Expansion project was more than 91 percent complete with an on-schedule startup expected in the fourth quarter 2009. Marathon now forecasts the project will cost approximately $3.7 billion. Delays in the receipt of materials and fabricated equipment contributed to revisions in work execution plans resulting in increased project costs. When completed, this expansion will increase the Garyville refinery's crude oil refining capacity by 180,000 bpd, improving scale efficiencies and feedstock flexibility.
Integrated Gas
Integrated Gas segment income was $13 million in the second quarter of 2009 compared to $102 million in the second quarter of 2008, primarily as a result of lower liquefied natural gas (LNG) price realizations. The LNG sales contract in Equatorial Guinea has a Henry Hub basis so the approximately 65 percent decline in this index had a dramatic effect on LNG profitability. The LNG facility in Equatorial Guinea continued to perform with high reliability during the second quarter of 2009, achieving operational availability of 99.6 percent. Marathon holds a 60 percent interest in the facility. Marathon's methanol realizations were also down during the second quarter. This was in line with methanol prices in the U.S. and European markets that averaged approximately $200 per metric tonne in the second quarter of 2009, down from approximately $485 per metric tonne in the same quarter of 2008.
The Company spent approximately $18 million on a pretax basis during the second quarter of 2009 on gas commercialization technologies, including its proprietary GTF(TM) technology, compared to the $22 million in the second quarter of 2008.
Three Months
Ended
June 30
2009 2008
---- ----
Key Integrated Gas Statistics
Net Sales (metric tonnes per day)
LNG 6,611 6,402
Methanol 1,362 1,188
--------- ----- -----
Corporate
Marathon has certain deferred income tax balances denominated in foreign currencies. Fluctuations in currency exchange rates cause the U.S. dollar value of these deferred tax balances to change with the related currency gains and losses reflected within the provision for income taxes. For the second quarter of 2009, Marathon's provision for income taxes included a $94 million foreign currency remeasurement loss related to its deferred income tax balances, primarily in Canada, compared to a $16 million foreign currency remeasurement loss in the same period of 2008.
Marathon expects the overall corporate effective income tax rate on adjusted pretax income to be between 54 and 59 percent for the full year 2009, excluding the effect of foreign currency remeasurement of deferred tax balances. For the second quarter 2009, the effective income tax rate on adjusted pretax income was 59 percent, which excluded the foreign currency remeasurement loss described above.
At June 30, 2009, Marathon's main sources of short-term liquidity amounted to approximately $4.5 billion, comprised of approximately $1.5 billion of cash equivalents and its full capacity under its $3 billion committed revolving credit facility.
Since launching its asset review and divestiture program in March 2008, Marathon's announced asset sales amount to approximately $3.2 billion in transaction values. These strategic divestitures have included the recently announced sale of an undivided 20 percent participating interest in Angola Block 32, all of Marathon's holdings in Ireland, interests in the Heimdal area offshore Norway, interests in the Permian Basin in Texas and New Mexico, the Company's ownership interest in Pilot Travel Centers, as well as other smaller transactions. Marathon continues to evaluate its portfolio of assets.
In July 2009, Marathon entered into a definitive agreement to sell an undivided 20 percent participating interest in the Production Sharing Contract and Joint Operating Agreement in Angola Block 32 to CNOOC International Limited and Sinopec International Petroleum Exploration and Production Corporation. The transaction has a total value of $1.3 billion, excluding any purchase price adjustments at closing, with an effective date of Jan. 1, 2009. The companies expect to close the transaction by year-end 2009, subject to Government and regulatory approvals. Marathon will retain a 10 percent working interest in Block 32.
Marathon has exited its Irish businesses and as a result, the activities of those businesses have been presented as discontinued operations and excluded from E&P segment income for all periods presented. The sale of Marathon International Petroleum Hibernia Limited, which included an 18.5 percent interest in the Corrib natural gas development, was completed in late July 2009. The transaction with Vermilion Energy Trust has an effective date of Jan. 1, 2009. The final transaction value will range between $235 million and $400 million, subject to the timing of first commercial gas at Corrib. An initial payment of $100 million plus working capital adjustments was received at closing in late July, with the remaining balance due at the time of first commercial gas. In April 2009, Marathon completed the sale of its wholly owned subsidiary, Marathon Oil Ireland Limited to PSE Ireland Limited, a subsidiary of Petroliam Nasional Berhad (Petronas). The transaction had a total value of $180 million with an effective date of Dec. 31, 2007.
In June 2009, Marathon completed the sale of its operated and a portion of its outside-operated assets in the Permian Basin of New Mexico and West Texas. The transactions had a total value of $301 million, with an effective date of Jan. 1, 2009.
Special Items
Marathon has two natural gas sales contracts in the United Kingdom that are accounted for as derivative instruments. Mark-to-market changes in the valuation of these contracts must be recognized in current period earnings. In the second quarter of 2009, the non-cash after-tax mark-to-market gain on these contracts related to sales of natural gas from the Brae field complex totaled $2 million. Due to the volatility in the fair value of these contracts, Marathon consistently excludes these non-cash gains and losses from adjusted net income. These contracts expire in September 2009.
As described above, Marathon has completed sales of certain of its Permian Basin properties, its operated properties in Ireland, and its outside-operated interest in the Corrib development in Ireland. The related net after-tax gain of $160 million has been excluded from adjusted net income.
The Company will conduct a conference call and webcast today, Aug. 3, at 2:00 p.m. EDT during which it will discuss second quarter results. The webcast will include synchronized slides. To listen to the webcast of the conference call and view the slides, visit the Marathon website at www.Marathon.com. Replays of the webcast will be available through Aug. 17, 2009. Quarterly financial and operational information is also provided on Marathon's Web site athttp://ir.marathon.com in the Quarterly Investor Packet.
# # #
In addition to net income determined in accordance with generally accepted accounting principles, Marathon has provided supplementally "adjusted net income," a non-GAAP financial measure which facilitates comparisons to earnings forecasts prepared by stock analysts and other third parties. Such forecasts generally exclude the effects of items that are considered non-recurring, are difficult to predict or to measure in advance or that are not directly related to Marathon's ongoing operations. A reconciliation between GAAP net income and "adjusted net income" is provided in a table on page 1 of this release. "Adjusted net income" should not be considered a substitute for net income as reported in accordance with GAAP. Management, as well as certain investors, uses "adjusted net income" to evaluate Marathon's financial performance between periods. Management also uses "adjusted net income" to compare Marathon's performance to certain competitors.
Cautionary Note to U.S. Investors: The United States Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose only proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions. Marathon Oil Corporation uses certain terms in this press release, such as contingent resource and net probable reserves, that the SEC's guidelines strictly prohibit Marathon from including in filings with the SEC. U.S. investors are urged to consider closely the disclosures in Marathon's periodic filings with the SEC, available from the Company at 5555 San Felipe, Houston, Texas 77056 and the Company's Web site athttp://www.Marathon.com. You can also obtain this information from the SEC by calling 1-800-SEC-0330.
This release contains forward-looking statements with respect to timing and levels of future production, the Volund development, the PSVM development, the Droshky development, the AOSP Phase 1 expansion, the Garyville Major Expansion project, and the anticipated sale of an undivided 20 percent participating interest in Angola Block 32. Factors that could potentially affect timing and levels of future production, the Volund development, the PSVM development and the Droshky development include pricing, supply and demand for petroleum products, the amount of capital available for exploration and development, regulatory constraints, timing of commencing production from new wells, drilling rig availability, unforeseen hazards such as weather conditions, acts of war or terrorist acts and the governmental or military response thereto, and other geological, operating and economic considerations. Factors that could affect the AOSP Phase 1 expansion, and the Garyville Major Expansion project include transportation logistics, availability of materials and labor, unforeseen hazards such as weather conditions, delays in obtaining or conditions imposed by necessary government and third-party approvals, and other risks customarily associated with construction projects. The sale of an undivided 20 percent participating interest in Angola Block 32 is subject to customary closing conditions, including Government and regulatory approvals. The foregoing factors (among others) could cause actual results to differ materially from those set forth in the forward-looking statements. In accordance with the "safe harbor" provisions of the Private Securities Litigation Reform Act of 1995, Marathon Oil Corporation has included in its Annual Report on Form 10-K for the year ended December 31, 2008, and subsequent Forms 10-Q and 8-K, cautionary language identifying other important factors, though not necessarily all such factors, that could cause future outcomes to differ materially from those set forth in the forward-looking statements.
Media Relations Contacts: Lee Warren 713-296-4103
Leslie Hiltabrand 713-296-4102
Investor Relations Contacts: Howard Thill 713-296-4140
Chris Phillips 713-296-3213
Condensed Consolidated Statements of Income
(Unaudited)
Three Months Ended Six Months Ended
(In millions, except per June 30, June 30
share data) 2009 2008 2009 2008
------------------------ ---- ---- ---- ----
Revenues and other income:
Sales and other operating
revenues
(including consumer excise
taxes) $13,059 $21,203 $23,213 $38,404
Sales to related parties 21 686 41 1,228
Income from equity method
investments 62 256 109 465
Net gain on disposal of
assets 191 12 195 22
Other income 25 45 77 104
-- -- -- ---
Total revenues and other
income 13,358 22,202 23,635 40,223
Costs and expenses:
Cost of revenues (excludes
items below) 9,776 17,985 17,133 32,400
Purchases from related
parties 110 226 205 365
Consumer excise taxes 1,226 1,295 2,400 2,511
Depreciation, depletion and
amortization 701 493 1,363 933
Selling, general and
administrative expenses 321 361 612 659
Other taxes 97 127 199 250
Exploration expenses 64 130 126 259
-- --- --- ---
Total costs and expenses 12,295 20,617 22,038 37,377
Income from operations 1,063 1,585 1,597 2,846
Net interest and other
financing costs (11) (11) (28) (4)
Income from continuing
operations before
income taxes 1,052 1,574 1,569 2,842
Provision for income taxes 711 806 962 1,357
--- --- --- -----
Income from continuing
operations 341 768 607 1,485
Discontinued operations 72 6 88 20
-- - -- --
Net income $413 $774 $695 $1,505
---------- ---- ---- ---- ------
Per Share Data
Basic:
Income from continuing
operations $0.48 $1.08 $0.86 $2.09
Discontinued operations $0.10 $0.01 $0.12 $0.02
Net income $0.58 $1.09 $0.98 $2.11
Diluted:
Income from continuing
operations $0.48 $1.07 $0.86 $2.07
Discontinued operations $0.10 $0.01 $0.12 $0.03
Net income $0.58 $1.08 $0.98 $2.10
Dividends paid $0.24 $0.24 $0.48 $0.48
-------------- ----- ----- ----- -----
Weighted Average Shares:
Basic 709 710 709 711
Diluted 711 714 711 716
---------- --- --- --- ---
Preliminary Supplemental Statistics (Unaudited)
Three Months Six Months
Ended Ended
(Dollars in millions, except June 30 June 30
as noted) 2009 2008 2009 2008
---------------------------- ---- ---- ---- ----
SEGMENT INCOME (LOSS)
Exploration and Production
United States $(41) $359 $(93) $603
International 261 463 398 891
--- --- --- ---
E&P segment 220 822 305 1,494
Oil Sands Mining 2 (157) (22) (130)
Refining, Marketing and
Transportation 165 158 324 83
Integrated Gas 13 102 40 201
-- --- -- ---
Segment Income 400 925 647 1,648
Items not allocated to
segments, net of income taxes:
Corporate and other
unallocated items (89) (57) (140) (78)
Foreign currency
remeasurement of
deferred taxes (94) (16) (66) 35
Gain (loss) on U.K.
natural gas contracts 2 (84) 44 (120)
Gain on disposal of assets 122 - 122 -
Gain on disposal of
discontinued operations 38 - 38 -
Discontinued operations 34 6 50 20
-- - -- --
Net income $413 $774 $695 $1,505
CAPITAL EXPENDITURES
Exploration and Production $617 $839 $990 $1,596
Oil Sands Mining 281 262 567 510
Refining, Marketing and
Transportation 713 702 1,373 1,213
Integrated Gas 1 - 1 1
Discontinued Operations 31 35 47 53
Corporate 7 7 8 9
- - - -
Total $1,650 $1,845 $2,986 $3,382
EXPLORATION EXPENSES
United States $31 $55 $65 $105
International 33 75 61 154
-- -- -- ---
Total $64 $130 $126 $259
----- --- ---- ---- ----
Preliminary Supplemental Statistics (Unaudited)
Three Months Six Months
Ended Ended
June 30 June 30
2009 2008 2009 2008
---- ---- ---- ----
E&P OPERATING STATISTICS
Net Liquid Hydrocarbon Sales
(mbpd)
United States 64 63 65 63
Europe 112 38 92 31
Africa 101 81 93 92
--- -- -- --
Total International 213 119 185 123
--- --- --- ---
Worldwide 277 182 250 186
Net Natural Gas Sales
(mmcfpd)(a)
United States 365 431 395 456
Europe 151 160 155 170
Africa 439 398 436 396
--- --- --- ---
Total International 590 558 591 566
--- --- --- ---
Worldwide Continuing
Operations 955 989 986 1,022
Discontinued Operations 3 15 33 44
- -- -- --
Worldwide 958 1,004 1,019 1,066
Total Worldwide Sales (mboepd)
Continuing Operations 436 347 415 357
Discontinued Operations 1 3 6 7
- - - -
Worldwide 437 350 421 364
Average Realizations (b)
Liquid Hydrocarbons (per bbl)
United States $53.25 $109.85 $44.84 $96.96
Europe 60.91 121.96 55.71 111.54
Africa 50.90 108.70 44.45 98.33
Total International 56.16 112.99 50.06 101.66
Worldwide $55.49 $111.90 $48.70 $100.07
Natural Gas (per mcf) \
United States $3.60 $8.66 $4.08 $7.70
Europe 4.43 7.43 4.90 7.56
Africa (c) 0.25 0.25 0.25 0.25
Total International 1.32 2.31 1.47 2.44
Worldwide Continuing
Operations 2.19 5.08 2.51 4.79
Discontinued Operations 7.49 12.37 8.54 8.83
Worldwide $2.21 $5.19 $2.71 $4.95
--------- ----- ----- ----- -----
(a) Includes natural gas acquired for injection and subsequent resale
of 18 mmcfpd and 25 mmcfpd in the second quarters of 2009 and 2008,
and 21 mmcfpd and 31 mmcfpd for the first six months of 2009 and
2008.
(b) Excludes gains and losses on derivative instruments (including the
unrealized effects of U.K. natural gas sales contracts that are
accounted for as derivatives).
(c) Primarily represents fixed prices under long-term contracts with
Alba Plant LLC, Atlantic Methanol Production Company LLC (AMPCO)
and Equatorial Guinea LNG Holdings Limited (EGHoldings), which are
equity method investees. Marathon includes its share of Alba
Plant LLC's income in the Exploration and Production segment and
its share of AMPCO's and EGHoldings' income in the Integrated Gas
segment.
Preliminary Supplemental Statistics (Unaudited) (continued)
Three Months Six Months
Ended Ended
(Dollars in millions, except June 30 June 30
as noted) 2009 2008 2009 2008
---------------------------- ---- ---- ---- ----
OSM OPERATING STATISTICS
Net Bitumen Production (mbpd) 26 24 25 24
Net Synthetic Crude Oil Sales
(mbpd) 30 31 31 31
Synthetic Crude Oil Average
Realization (per bbl) (d) $55.02 $116.40 $46.63 $102.70
------------------------------ ------ ------- ------ -------
RM&T OPERATING STATISTICS
Refinery Runs (mbpd)
Crude oil refined 959 1,023 905 934
Other charge and blend stocks 199 180 210 207
--- --- --- ---
Total 1,158 1,203 1,115 1,141
Refined Product Yields (mbpd)
Gasoline 659 607 638 604
Distillates 319 367 314 326
Propane 23 23 22 22
Feedstocks and special products 73 116 62 108
Heavy fuel oil 25 23 24 27
Asphalt 75 86 70 73
-- -- -- --
Total 1,174 1,222 1,130 1,160
Refined Products Sales Volumes
(mbpd)(e) 1,371 1,369 1,329 1,324
Refining and Wholesale
Marketing Gross
Margin (per gallon) (f) $0.0871 $0.0835 $0.0833 $0.0420
Speedway SuperAmerica
Retail outlets 1,611 1,625 - -
Gasoline and distillate sales
(millions of gallons) 806 788 1,590 1,580
Gasoline and distillate gross
margin (per gallon) $0.1051 $0.0862 $0.1059 $0.1005
Merchandise sales $809 $722 $1,499 $1,369
Merchandise gross margin $192 $181 $370 $344
------------------------ ---- ---- ---- ----
IG OPERATING STATISTICS
Net Sales (metric tonnes per
day)(g)
LNG 6,611 6,402 6,690 6,657
Methanol 1,362 1,188 1,258 1,159
--------- ----- ----- ----- -----
(d) Excludes gains and losses on derivative instruments.
(e) Total average daily volumes of all refined product sales to
wholesale, branded and retail customers.
(f) Sales revenue less cost of refinery inputs, purchased products and
manufacturing expenses, including depreciation.
(g) Includes both consolidated sales volume and Marathon's share of
sales volumes of equity method investees. LNG sales from Alaska
are conducted through a consolidated subsidiary. LNG and methanol
sales from Equatorial Guinea are conducted through equity method
investees.
