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Form 8-K MARATHON OIL CORP For: Feb 18

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February 18, 2015 5:08 PM EST



UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
 
 
 
Date of Report (Date of Earliest Event Reported):
 
February 18, 2015


Marathon Oil Corporation
__________________________________________
(Exact name of registrant as specified in its charter)
 
 
 
Delaware
1-5153
25-0996816
_____________________
 (State or other jurisdiction
_____________
 (Commission
______________
 (I.R.S. Employer
of incorporation)
File Number)
Identification No.)
  
 
 
5555 San Felipe Street, Houston, Texas
 
77056
_________________________________
 (Address of principal executive offices)
 
___________
 (Zip Code)
 
 
 
Registrant's telephone number, including area code:
 
(713) 629-6600

Not Applicable
______________________________________________
Former name or former address, if changed since last report

 

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

[  ] Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
[  ]  Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
[  ]  Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
[  ]  Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))










Item 2.02 Results of Operations and Financial Condition.

On February 18, 2015, Marathon Oil Corporation issued a press release announcing results for the full year and quarter ended December 31, 2014. The press release is furnished as Exhibit 99.1 to this report and is incorporated herein by reference.

The information in this Current Report on Form 8-K, including Exhibit 99.1 furnished herewith, shall not be deemed to be "filed" for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), and will not be incorporated by reference into any filing under the Exchange Act or the Securities Act of 1933, as amended, unless specifically identified therein as being incorporated therein by reference.



Item 9.01 Financial Statements and Exhibits.

(d) Exhibits
99.1 Press Release issued by Marathon Oil Corporation, dated February 18, 2015.









SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
 
 
 
 
 
 
 
Marathon Oil Corporation
  
 
 
 
 
February 18, 2015
 
By:
 
 /s/ Gary E. Wilson
 
 
 
 



 
 
 
 
Name: Gary E. Wilson
 
 
 
 
Title: Vice President, Controller and Chief Accounting Officer





Exhibit Index


99.1 Press Release issued by Marathon Oil Corporation, dated February 18, 2015.




Exhibit 99.1
Marathon Oil Announces Full-Year and Fourth Quarter 2014 Results
Proved Reserve Replacement 183% and Resource Play Production Up 35% Year Over Year
 
HOUSTON, Feb. 18, 2015 - Marathon Oil Corporation (NYSE: MRO) today reported full-year 2014 adjusted net income from continuing operations of $1.16 billion, or $1.70 per diluted share, and adjusted net income of $1.729 billion, or $2.53 per diluted share, excluding the impact of certain items not typically represented in analysts' earnings estimates and that would otherwise affect comparability of results. Reported income from continuing operations for full-year 2014 was $969 million, or $1.42 per diluted share, and reported net income was $3.046 billion, or $4.46 per diluted share.

Full-year 2014 Highlights
•
Achieved 35% production growth from U.S. resource plays year over year with average net production of 181,000 boed; Eagle Ford, Bakken and Oklahoma Resource Basins up 38%, 31% and 29%, respectively
•
Total Company production available for sale from continuing operations (excluding Libya) up 8% year over year
•
Grew U.S. unconventional net 2P resource to 3 billion boe, up more than 20% over year-end 2013
•
Proved reserve replacement of 183%, excluding dispositions, at approximately $20 per boe finding & development cost
•
Recorded 97% average operational availability for Company-operated assets
•
Closed Norway and Angola sales for aggregate cash proceeds of more than $4 billion
•
Completed $1 billion in share repurchases in the first half of 2014
•
Increased quarterly dividend in the second quarter by 11% to $0.21 per share
•
Year-end liquidity of $4.9 billion comprised of $2.4 billion in cash and $2.5 billion available through a committed multi-year credit facility

The Company reported a fourth quarter 2014 adjusted loss from continuing operations of $89 million, or $0.13 per diluted share, and adjusted net loss of $2 million. Reported loss from continuing operations for fourth quarter 2014 was $93 million, or $0.14 per diluted share, and reported net income was $926 million, or $1.37 per diluted share.

Fourth Quarter Operational Highlights
•
U.S. resource plays averaged net production of 206,000 boed, up 43% from the year-ago quarter and 7% higher than third quarter 2014
◦
Record 98 gross operated Eagle Ford wells to sales, up 13% over third quarter
▪
11 Austin Chalk and initial four Upper Eagle Ford wells to sales
◦
Bakken production increased 38% over year-ago quarter
▪
17 gross operated Bakken wells to sales, of which 15 piloted enhanced completions
▪
Enhanced completion designs achieving promising results with 42 of 55 tests online
▪
18 pilot completion wells averaging greater than 30% uplift in cumulative production over the first 60 days
◦
Four gross operated SCOOP wells to sales in the Oklahoma Resource Basins, including one extended-reach lateral (XL) with 30-day initial production (IP) rate of 1,065 boed (63% crude oil/condensate, 21% NGLs)
◦
Executed agreements for additional 10,000 net acres in the SCOOP; approximately 70% of acreage in Oklahoma held by production as of year end
•
Recorded 98% average operational availability for Company-operated assets
•
Two U.K. South Brae infill wells delivering production rates well above pre-drill estimates

“Marathon Oil delivered against our performance commitments in 2014, increasing production by 35 percent in our three highest-value resource plays, successfully marketing our Norway and Angola assets, and executing share repurchases in the first half of the year worth $1 billion," Marathon Oil President and CEO Lee M. Tillman said. "Overall we recorded 97 percent operational availability for Company-operated assets during the year. Additionally, our proved reserve replacement was 183 percent at a competitive finding and development cost. Our North America E&P operations added net proved reserves of 288 million boe -- mainly due to downspacing, drilling activity and improved well performance -- amounting to a 37 percent increase over the prior year's ending balance.

“The second half of 2014 brought a rapid correction in commodity prices and our fourth quarter North America crude oil and condensate realizations were down 26 percent sequentially," Tillman added. "Though our U.S. resource plays generate competitive returns at current pricing, we're taking action to materially reduce our 2015 capital program relative to 2014 to protect our financial flexibility. Marathon Oil is well prepared -- we re-shaped our portfolio to concentrate on higher margin, higher return opportunities and have the optionality to adjust our short-cycle investments in line with commodity volatility.

"We are not opportunity limited and in fact, the current environment simply serves to underscore the importance of subsurface quality and execution at scale -- advantages that are common to our positions in the Eagle Ford, Bakken and Oklahoma Resource Basins. Our deep, multi-year drilling inventory is robust across a broad range of pricing scenarios and positions us strongly for a commodity price recovery. In the interim, we intend to pursue all options to expand our margins during this period of uncertainty -- capital efficiency, investment high grading, early capture of service cost reductions, expense management and operational reliability.

"Though we have rightly focused on prudent near-term actions, Marathon Oil has laid the groundwork for the future by growing our U.S. unconventional net 2P resource by 20 percent in 2014. Our asset teams continue to aggressively test downspacing, completion designs, co-development and new horizons which offer the potential to add further to our 3 billion barrels of oil equivalent of net 2P unconventional resource," Tillman said.

 
Three Months Ended
Year Ended
 
Dec. 31
Dec. 31
Dec. 31
Dec. 31
(In millions, except per diluted share data)
2014 (a)
2013 (a)
2014 (a)
2013 (a)
Adjusted income (loss) from continuing operations (b)
$(89)
$179
$1,160
$1,052
Adjustments for special items (net of taxes):
 
 
 
 
Net gain (loss) on dispositions
0
(11)
(58)
(20)
Impairments
0
(29)
(70)
(39)
Pension settlement
(4)
(9)
(63)
(29)
Unrealized loss on crude oil derivative instruments
0
6
0
(33)
Income (loss) from continuing operations
$(93)
$136
$969
$931
Per diluted share:
 
 
 
 
Adjusted income (loss) from continuing operations (b)
$(0.13)
$0.26
$1.70
$1.48
Income (loss) from continuing operations
$(0.14)
$0.20
$1.42
$1.31
Adjusted net income (loss) (b)
$(2)
$418
$1,729
$1,874
Adjustments for special items (net of taxes):
 
 
 
 
Net gain (loss) on dispositions
932
(11)
1,450
(20)
Impairments
0
(29)
(70)
(39)
Pension settlement
(4)
(9)
(63)
(29)
Unrealized gain (loss) on crude oil derivative instruments
0
6
0
(33)
Net income
$926
$375
$3,046
$1,753
Per diluted share:
 
 
 
 
Adjusted net income (b)
$0.00
$0.60
$2.53
$2.64
Net income
$1.37
$0.54
$4.46
$2.47
Exploration expenses
 
 
 
 
Unproved property impairments
$166
$115
$306
$572
Dry well costs
237
52
317
148
Geological and geophysical
58
36
85
80
Other
18
23
85
91
Total exploration expenses
$479
$226
$793
$891
Cash flows
 
 
 
 
Net cash provided by continuing operations before changes in working capital (b)
$768
$934
$4,661
$4,398
Changes in working capital for continuing operations
492
154
75
(10)
Total net cash provided by continuing operations
1,260
1,088
4,736
4,388
Net cash provided by discontinued operations
(105)
141
751
882
Net cash provided by operating activities
$1,155
$1,229
$5,487
$5,270
(a) The Company closed on the sale of its Angola assets in first quarter 2014 and its Norway business in fourth quarter 2014. The Angola and Norway businesses are reflected as discontinued operations in all periods presented.
(b) Non-GAAP financial measure. See "Non-GAAP Measures" below for further discussion.

Reserves
Driven by strong reserves growth in the Company’s U.S. resource plays, Marathon Oil’s total net proved reserves were approximately 2.2 billion barrels of oil equivalent (boe) at the end of 2014, an increase of 6 percent over the prior year for continuing operations. The net proved reserve base is 80 percent liquids and 67 percent proved developed. The Company’s reserve replacement ratio, excluding dispositions, was 183 percent, with 305 million boe of net proved reserves added during 2014. Including the divestitures of Angola and Norway businesses, the Company maintained positive overall reserve growth and a reserve replacement ratio of 116 percent. The Company's finding and development cost was approximately $20 per boe.




Net additions, including acquisitions, were driven primarily by U.S. resource play activity in the Eagle Ford, Bakken and Oklahoma Resource Basins. In 2014, North America E&P operations added 296 million boe, amounting to an increase of 38 percent over the prior year's ending balance, mainly due to downspacing, drilling activity and improved well performance.

Marathon Oil added a total of 237 million barrels of net proved liquids [crude oil and condensate (C&C), natural gas liquids (NGLs) and synthetic crude oil (SCO)] reserves, resulting in a total liquids reserve replacement ratio, excluding dispositions, of 235 percent related to continuing operations.

Estimated Net Proved Reserves
 
North America E&P
International E&P
OSM
Subtotal Cont. Ops
Disc. Ops
Total
 
Total (mmboe)
Total (mmboe)
SCO (mmbbl)
(mmboe)
(mmboe)
(mmboe)

As of Dec. 31, 2013
787
598
680
2,065
106
2,171
Additions
252
15
0
267
3
270
Revisions
36
(3)
(55)
(22)
11
(11)
Acquisitions
8
0
38
46
0
46
Dispositions
(10)
0
0
(10)
(101)
(111)
Production
(87)
(46)
(15)
(148)
(19)
(167)
As of Dec. 31, 2014
986
564
648
2,198
0
2,198
Reserve Replacement Ratio (including acquisitions & dispositions)

 
 
 
116
%
Reserve Replacement Ratio (excluding dispositions)

 
 
 
183
%

For the three-year period ended Dec. 31, 2014, Marathon Oil added net proved reserves of slightly more than 1 billion boe, excluding dispositions, resulting in a three-year average reserve replacement ratio of 201 percent.

Sales and Production Volumes
Total Company sales volumes from continuing operations (excluding Libya) averaged 442,000 net barrels of oil equivalent per day (boed) during fourth quarter 2014 and 408,000 net boed for full-year 2014, compared to 379,000 net boed for fourth quarter 2013 and 376,000 net boed for full-year 2013.

 
Three Months Ended
Year Ended
 
Dec. 31
Dec. 31
Dec. 31
Dec. 31
(mboed)
2014
2013
2014
2013
Net Sales Volumes
 
 
 
 
North America E&P
262
206
238
201
International E&P excluding Libya (a) and Disc Ops (b)
125
122
120
127
Combined North America & International E&P, excluding Libya (a) and Disc Ops (b)
387
328
358
328
Oil Sands Mining (c)
55
51
50
48
Total Continuing Operations excluding Libya
442
379
408
376
Discontinued Operations (Norway)
10
73
52
79
Discontinued Operations (Angola)
0
11
2
10
Total Company excluding Libya
452
463
462
465
Libya
22
1
7
28
Total
474
464
469
493
(a) Libya is excluded because of uncertainty around future production and sales levels.
(b) Angola and Norway are reflected as discontinued operations (Disc Ops).
(c) Includes blendstocks.

Total Company production available for sale from continuing operations (excluding Libya) averaged 399,000 net boed for full-year 2014 compared to 371,000 net boed for 2013, an 8 percent increase year-over-year. The difference between production volumes available for sale and recorded sales for exploration and production (E&P) volumes was primarily due to the timing of international liftings.

 
Three Months Ended
Year Ended
 
Dec. 31
Dec. 31
Dec. 31
Dec. 31
(mboed)
2014
2013
2014
2013
Net Production Available for Sale
 
 
 
 
North America E&P
262
206
238
201
International E&P excluding Libya (a) and Disc Ops (b)
126
129
120
128
Combined North America & International E&P, excluding Libya (a) and Disc Ops (b)

388
335
358
329
Oil Sands Mining (c)
42
46
41
42
Total Continuing Operations excluding Libya
430
381
399
371
Discontinued Operations (Norway)
9
77
51
79
Discontinued Operations (Angola)
0
11
2
9
Total Company excluding Libya
439
469
452
459
Libya
22
2
8
28
Total
461
471
460
487
(a) Libya is excluded because of uncertainty around future production and sales levels.
(b) Angola and Norway are reflected as Disc Ops.
(c) Upgraded bitumen excluding blendstocks.

Fourth quarter 2014 production available for sale from continuing operations (excluding Libya) averaged 430,000 net boed, compared to fourth quarter 2013 average of 381,000 net boed, a 13 percent increase over the prior year quarter. The increase was driven by North America E&P's continued growth in the U.S. resource plays, which was up 43 percent compared to the year-ago quarter.

International E&P production available for sale from continuing operations (excluding Libya) for fourth quarter 2014 was lower compared to fourth quarter 2013, reflecting natural decline in Equatorial Guinea and significant planned and unplanned maintenance at the outside-operated Foinaven oil field.

Oil Sands Mining (OSM) production available for sale for fourth quarter 2014 was down 10 percent, primarily a result of planned maintenance at the Muskeg River and Jackpine mines, compared to fourth quarter 2013.

In Libya, Marathon Oil had four liftings in early fourth quarter 2014. In December, Libya's National Oil Corporation declared force majeure at the Es Sider terminal, as disruptions from civil unrest continue. Considerable uncertainty remains around future timing of production and sales levels, and Marathon Oil continues to exclude production from Libya in its production forecasts.

The Company's first quarter and full-year 2015 production guidance, as shown in the table below, is reflective of the Company's 2015 capital, investment and exploration budget of $3.5 billion. The full-year guidance reflects a total Company (excluding Libya) growth rate of 5 to 7 percent year over year. The Company's capital budget and 2015 guidance is further outlined in a separate news release issued today, Feb. 18, 2015.

 
Guidance (a)
Guidance (a)
 
1Q
Full-Year
(mboed)
2015
2015
Net Production Available for Sale
 
 
North America E&P
268-279
 
International E&P excluding Libya (b)
107-116
 
Combined North America & International E&P, excluding Libya (b)
375-395
370-390
Oil Sands Mining (c)
40-45
35-45
(a) This guidance excludes the effect of acquisitions or dispositions not previously announced.
(b) Libya is excluded because of uncertainty around future production and sales levels.
(c) Upgraded bitumen excluding blendstocks.

Segment Results
Total segment income/loss from continuing operations was a loss of $39 million in fourth quarter 2014 and income of $1.5 billion for the full-year 2014, compared to income of $290 million in fourth quarter 2013 and $1.49 billion for full-year 2013.
 
Three Months Ended
Year Ended
 
Dec. 31
Dec. 31
Dec. 31
Dec. 31
(In millions)
2014
2013
2014
2013
Segment Income (Loss)
 
 
 
 
North America E&P
$(143)
$125
$693
$529
International E&P (a)
81
123
568
758
Oil Sands Mining
23
42
235
206
  Segment Income (Loss) (b)
$(39)
$290
$1,496
$1,493
(a) The Company closed on the sale of its Angola assets in first quarter 2014 and its Norway business in fourth quarter 2014. The Angola and Norway businesses are reflected as discontinued operations in all periods presented.
(b) See Supplemental Statistics below for a reconciliation of segment income (loss) to net income.

North America E&P
The North America E&P segment reported a loss of $143 million in fourth quarter 2014 compared to income of $125 million in fourth quarter 2013. The decrease was primarily due to lower crude oil price realizations combined with higher exploration expenses, partially offset by higher net sales volumes from the U.S. resource plays. North America exploration expense in fourth quarter 2014 included dry well costs of $211 million (pre-tax) and total unproved property impairments of $166 million (pre-tax) onshore U.S. and Gulf of Mexico. Costs related to the Company-operated Key Largo, and outside-operated Perseus and second Shenandoah appraisal well in the Gulf of Mexico were included in exploration expense during the quarter.

The North America E&P segment income for the full-year 2014 was $693 million compared to $529 million for 2013. The increase in 2014 was primarily due to higher net sales volumes from the U.S. resource plays and lower exploration expenses, partially offset by lower average price realizations.

Production in the Eagle Ford, Bakken and Oklahoma Resource Basins combined to average 206,000 net boed during fourth quarter 2014, up 43 percent from the year-ago quarter and 7 percent higher than third quarter 2014. For full-year 2014, the resource plays increased production 35 percent year over year, averaging 181,000 net boed during the year, compared with 134,000 net boed in 2013.

EAGLE FORD: In fourth quarter 2014 Marathon Oil's production in the Eagle Ford averaged 131,000 net boed, a 46 percent increase over the year-ago quarter and 12 percent over the previous quarter. Approximately 65 percent of fourth quarter net production was crude oil/condensate, 17 percent was NGLs and 18 percent was natural gas. Marathon Oil reached total depth on 96 gross operated wells and brought a record 98 gross operated wells to sales in the fourth quarter, compared to 93 and 87 gross wells, respectively, in third quarter 2014. Marathon Oil's average time to drill an Eagle Ford well in fourth quarter 2014, spud-to-total depth, improved to 12 days. The Company's high-density pad drilling continues to average four wells per pad.

Included with the Eagle Ford well counts noted above, the Company brought online 11 gross operated Austin Chalk wells. For the year 2014, the Company brought to sales a total of 22 gross operated Austin Chalk wells that delineated 18,000 net acres, and 14 additional Austin Chalk wells are currently being drilled, completed or awaiting first production. The first four Upper Eagle Ford wells were brought online late in the fourth quarter, and the Company spud its first four-well "stack-and-frack" pilot with Austin Chalk, Upper Eagle Ford and two Lower Eagle Ford wells.

BAKKEN: Marathon Oil averaged 55,000 net boed of production in the Bakken during fourth quarter 2014, an increase of 38 percent over the year-ago average and flat compared to the previous quarter as a result of increased density pad drilling and the timing of bringing wells to sales. The Company's Bakken production averaged 88 percent crude oil, 6 percent NGLs and 6 percent natural gas. The Company reached total depth on 23 gross operated wells and brought 17 gross operated wells to sales in the fourth quarter, compared to 25 gross wells reaching total depth and 19 brought to sales in third quarter 2014. The Company's time to drill a Bakken well, spud-to-total depth, averaged 16 days in the fourth quarter.
The Bakken enhanced completion design pilot program is achieving promising early results with 42 of the 55 tests online at year end. The initial results, based on 18 wells, are showing greater than 30 percent improvement in cumulative production after 60 days, compared to direct offset performance. The Company has recently finished drilling two high-density spacing pilots (six wells per horizon) that are awaiting completion, with a third currently drilling.

OKLAHOMA RESOURCE BASINS: The Company's unconventional Oklahoma production averaged 20,000 net boed during fourth quarter 2014, an increase of 43 percent over the year-ago average and up 5 percent compared to the previous quarter. Approximately 45 percent of fourth quarter 2014 net production was liquids and 55 percent was natural gas. During the fourth quarter, the Company reached total depth on four gross operated wells and brought four gross operated wells to sales, all in the South Central Oklahoma Oil Province (SCOOP). Of the wells, one was an extended-reach lateral (XL) well drilled in the updip, highly liquids-rich area of the SCOOP, with a 30-day IP rate of 1,065 boed (63 percent crude oil/condensate, 21 percent NGLs). Marathon Oil executed agreements for an additional 10,000 net acres in the SCOOP, including acres with Springer potential.
International E&P
International E&P segment income was $81 million in fourth quarter 2014, compared to segment income of $123 million in fourth quarter 2013. Exploration expense included dry well costs for the Sodalita West in Equatorial Guinea. For full-year 2014, International E&P segment income was $568 million compared to $758 million in 2013. The decrease in 2014 is primarily due to lower liquid hydrocarbon price realizations, lower sales volumes, and higher other operating expenses.

EQUATORIAL GUINEA: Production available for sale averaged 106,000 net boed in fourth quarter 2014, compared to 109,000 net boed in the year-ago quarter and 100,000 net boed in the previous quarter.

U.K.: Production available for sale averaged 20,000 net boed in fourth quarter 2014, relatively flat compared to fourth quarter 2013, despite natural decline within the Brae fields. Production was up more than 50 percent over the previous quarter, largely due to third quarter planned maintenance activity and two South Brae infill wells brought online late in the third quarter with initial production rates above pre-drill estimates.

KURDISTAN REGION OF IRAQ: In December, Marathon Oil announced the Jisik-1 exploration well had discovered multiple stacked oil and natural gas producing zones on the Company-operated Harir Block. A drill-stem testing program yielded a sustained flow rate of 6,100 barrels per day of oil, and multiple non-associated gas zones flowed at a combined rate of approximately 10-15 million cubic feet per day, without stimulation, together with associated condensate, all of which were equipment constrained. The well has been suspended for potential future use as a producing well. Additionally, the Mirawa-2 appraisal well was spud in December and is expected to reach total depth in the second quarter. Marathon Oil holds a 45 percent working interest in the Harir Block.

On the outside-operated Sarsang block, the East Swara Tika-1 exploration well is being sidetracked up-dip. Discussions are ongoing with the Ministry of Natural Resources to finalize the Swara Tika field development plan. Marathon Oil holds a 20 percent working interest in the Sarsang Block.

GABON: In early November, the Company began acquisition of 3D seismic on the Company-operated Tchicuate Block in Gabon. The seismic program is expected to be completed in the second quarter, and processing will occur through the remainder of the year.

CROATIA: Marathon Oil was awarded, as part of a consortium, seven blocks located offshore in the Adriatic Sea, subject to negotiation of a production sharing contract (PSC) with the Croatian Government. Marathon Oil has a 60 percent interest and operatorship in the consortium.
Oil Sands Mining
The OSM segment reported income of $23 million for fourth quarter 2014, compared to $42 million in fourth quarter 2013. The decrease was primarily a result of lower price realizations partially offset by higher net sales volumes. The OSM segment reported full-year 2014 income of $235 million compared to $206 million for 2013. The increase was primarily a result of higher operating expenses in the prior year.

Corporate and Special Items
Included in the adjustments to net income for fourth quarter 2014 was a net $932 million after-tax gain related to discontinued operations. The Company also recorded an after-tax settlement charge of $4 million ($6 million pre-tax) in connection with its U.S. pension plans.

The Company's webcast commentary and associated slides related to Marathon Oil's earnings, as well as the Quarterly Investor Packet, will be posted to the Company's website at http://ir.marathonoil.com and to its mobile app as soon as practicable following this release today, Feb. 18. Marathon Oil also issued a separate release today detailing its 2015 capital, investment and exploration budget. The Company will conduct a question and answer webcast/call covering both earnings and 2015 budget on Thursday, Feb. 19 at 9 a.m. EST. The webcast slides, associated commentary and answers to questions will include forward-looking information. To listen to the live webcast, visit the Marathon Oil website at http://www.marathonoil.com. Replays of the webcast will be available through March 19, 2015.

# # #
Non-GAAP Measures
Adjusted net income and adjusted net income per diluted share, non-GAAP financial measures, facilitate 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 Oil's ongoing operations. See the first table of this release for a reconciliation between adjusted net income and net income, its most directly comparable GAAP financial measure. Adjusted net income and adjusted net income per diluted share should not be considered substitutes for net income and net income per diluted share as reported in accordance with GAAP. Management uses adjusted net income to evaluate Marathon Oil's financial performance between periods and to compare Marathon Oil's performance to certain competitors.

Adjusted income (loss) from continuing operations and adjusted income (loss) from continuing operations per diluted share, non-GAAP financial measures, facilitate 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 Oil's ongoing operations and can exclude the impact of discontinued operations. See the first table of this release for a
reconciliation between adjusted income (loss) from continuing operations and income (loss) from continuing operations, its most directly comparable GAAP financial measure. Adjusted income (loss) from continuing operations and adjusted income (loss) from continuing operations per diluted share should not be considered substitutes for income (loss) from continuing operations and income (loss) from continuing operations per diluted share as reported in accordance with GAAP. Management uses adjusted income (loss) from continuing operations to evaluate Marathon Oil's financial performance between periods and to compare Marathon Oil's performance to certain competitors.

Management believes net cash provided by continuing operations before changes in working capital, a non-GAAP financial measure, demonstrates the Company's ability to internally fund capital expenditures, pay dividends and service debt. See the first table of this release for a reconciliation between net cash provided by continuing operations before changes in working capital and net cash provided by operating activities, its most directly comparable GAAP financial measure. Net cash provided by continuing operations before changes in working capital should not be considered a substitute for net cash provided by operating activities as reported in accordance with GAAP. Management uses net cash provided by continuing operations before changes in working capital to evaluate Marathon Oil's financial performance between periods and to compare Marathon Oil's performance to certain competitors.

Forward-looking Statements
This release contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements are statements other than statements of historical fact that give current expectations or forecasts of future events. They include, but are not limited to: the Company’s operational, financial and growth strategies, including planned capital expenditures and the impact thereof, growth activities and expectations, future drilling plans and projects, timing and expectations, seismic expectations, future production and sales expectations, future drilling inventory, and well spud timing and expectations; the Company’s ability to successfully effect those strategies and the expected results therefrom; the Company’s financial and operational outlook, and ability to fulfill that outlook; expectations regarding future economic and market conditions and their effects on the Company; the Company's 2015 capital, investment and exploration budget; the Company's financial position, liquidity and capital resources, and the benefits thereof and opportunities provided thereby; resource, inventory and asset quality and the expected benefits and performance thereof; reserve estimates and growth expectations; 2P resource estimates; 2015 production guidance, growth expectations and the drivers thereof; and statements related to enhanced completion designs, downspacing, co-development, stac and frac pilots, high density pilots, and the expected benefits and results thereof. While the Company believes that the assumptions concerning future events are reasonable, a number of factors could cause results to differ materially from those indicated by such forward-looking statements including, but not limited to: conditions in the oil and gas industry, including the level of supply or demand for liquid hydrocarbons and natural gas and the impact on the price of liquid hydrocarbons and natural gas; changes in expected levels of reserves or production; changes in political or economic conditions in key operating markets, including international markets; the amount of capital available for exploration and development; timing of commencing production from new wells; drilling rig availability; availability of materials and labor; the inability to obtain or delay in obtaining necessary government or third-party approvals and permits; non-performance by third parties of their contractual obligations; unforeseen hazards such as weather conditions, acts of war or terrorist acts and the governmental or military response thereto; cyber-attacks that adversely affect operations; changes in safety, health, environmental and other regulations; and other geological, operating and economic considerations. These forward-looking statements are also affected by the risk factors, forward-looking statements and challenges and uncertainties described in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013, and those set forth from time to time in the Company’s filings with the Securities and Exchange Commission, which are currently available at www.marathonoil.com. Except as required by law, the Company expressly disclaims any intention or obligation to revise or update any forward-looking statements whether as a result of new information, future events or otherwise.

The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable or possible reserves which are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. The Company uses certain terms in this release, such as unconventional net 2P resource and other similar terms, that the SEC's guidelines strictly prohibit us from including in filings with the SEC. U.S. investors are urged to consider closely the disclosures in the Company’s periodic filings with the SEC, available on the Company's website at www.marathonoil.com. You can also obtain this information from the SEC by calling 1-800-SEC-0330 or from the SEC's website at www.sec.gov.

Editor's Note:
2P - Most likely or "2P" volumes represent most likely deterministic estimates of proved plus probable reserves as defined by the SEC, plus contingent or "2C" volumes with the same technical certainty as proved and probable reserves that are expected to be recovered but that cannot yet be classified as reserves, or the P50 on the cumulative distribution of results from probabilistic estimates.


Media Relations Contacts:
Lee Warren: 713-296-4103
Lisa Singhania: 713-296-4101

Investor Relations Contact:
Chris Phillips: 713-296-3213
Zach Dailey: 713-296-4140



Consolidated Statements of Income (Unaudited)
Three Months Ended
Year Ended
 
Dec. 31
Sept. 30
Dec. 31
Dec. 31
Dec. 31
(In millions, except per share data)
2014
2014
2013
2014
2013
Revenues and other income:
 
 
 
 
 
   Sales and other operating revenues, including related party
$2,001
$2,316
$1,951
$8,736
$9,246
   Marketing revenues
397
554
484
2,110
2,079
   Income from equity method investments
78
89
114
424
423
   Net loss on disposal of assets
(2)
(3)
(25)
(90)
(29)
   Other income
23
15
26
78
64
Total revenues and other income
2,497
2,971
2,550
11,258
11,783
Costs and expenses:
 
 
 
 
 
   Production
549
593
531
2,246
2,156
   Marketing, including purchases from related parties
395
554
486
2,105
2,076
   Other operating
159
99
106
462
389
   Exploration
479
96
226
793
891
   Depreciation, depletion and amortization
801
737
586
2,861
2,500
   Impairments
2
109
47
132
96
   Taxes other than income
87
115
81
406
345
   General and administrative
168
160
194
654
659
Total costs and expenses
2,640
2,463
2,257
9,659
9,112
Income (loss) from operations
(143)
508
293
1,599
2,671
   Net interest and other
(58)
(55)
(67)
(238)
(278)
Income (loss) from continuing ops before income taxes
(201)
453
226
1,361
2,393
   Provision (benefit) for income taxes
(108)
149
90
392
1,462
Income (loss) from continuing operations
(93)
304
136
969
931
Discontinued operations (a)
1,019
127
239
2,077
822
Net income
$926
$431
$375
$3,046
$1,753
Per Share Data
 
 
 
 
 
Basic:
 
 
 
 
 
Income (loss) from continuing operations
$(0.14)
$0.45
$0.20
$1.42
$1.32
Discontinued operations (a)
$1.51
$0.19
$0.34
$3.06
$1.17
Net income
$1.37
$0.64
$0.54
$4.48
$2.49
Diluted:
 
 
 
 
 
Adjusted net income (b)
$0.00
$0.76
$0.60
$2.53
$2.64
Adjusted income (loss) from continuing operations (b)
$(0.13)
$0.57
$0.26
$1.70
$1.48
Income (loss) from continuing operations
$(0.14)
$0.45
$0.20
$1.42
$1.31
Discontinued operations (a)
$1.51
$0.19
$0.34
$3.04
$1.16
Net income
$1.37
$0.64
$0.54
$4.46
$2.47
Weighted Average Shares:
 
 
 
 
 
Basic
675
675
697
680
705
Diluted
677
678
701
683
709
(a) The Company closed on the sale of its Angola assets in first quarter 2014 and its Norway business in fourth quarter 2014. The Angola and Norway businesses are reflected as discontinued operations in all periods presented.
(b) Non-GAAP financial measure. See "Non-GAAP Measures" above for further discussion.

Supplemental Statistics (Unaudited)
Three Months Ended
Year Ended
 
Dec. 31
Sept. 30
Dec. 31
Dec. 31
Dec. 31
(in millions)
2014
2014
2013
2014
2013
Segment Income (Loss)
 
 
 
 
 
North America E&P
$(143)
$292
$125
$693
$529
International E&P
81
106
123
568
758
Oil Sands Mining
23
93
42
235
206
Segment income (loss)
(39)
491
290
1,496
1,493
Items not allocated to segments, net of income taxes:
 
 
 
 
 
Corporate and unallocated
(50)
(103)
(111)
(336)
(441)
Impairments
0
(70)
(29)
(70)
(39)
Pension settlement
(4)
(14)
(9)
(63)
(29)
Unrealized gain (loss) on crude oil derivative instruments
0
0
6
0
(33)
Net gain (loss) on dispositions
0
0
(11)
(58)
(20)
Income (loss) from continuing operations
(93)
304
136
969
931
Discontinued operations (a)
1,019
127
239
2,077
822
Net income
$926
$431
$375
$3,046
$1,753
Capital Expenditures (c)
 
 
 
 
 
North America E&P
$1,452
$1,277
$943
$4,698
$3,649
International E&P
148
166
142
534
456
Oil Sands Mining
40
49
77
212
286
Discontinued Operations (a)
14
125
122
390
535
Corporate
22
16
11
51
58
Total
$1,676
$1,633
$1,295
$5,885
$4,984
Exploration Expenses
 
 
 
 
 
North America E&P
$414
$55
$166
$608
$725
International E&P
65
41
60
185
166
Total
$479
$96
$226
$793
$891
Provision (benefit) for Income Taxes
 
 
 
 
 
Current income taxes
$141
$(15)
$122
$304
$1,496
Deferred income taxes
(249)
164
(32)
88
(34)
Total
$(108)
$149
$90
$392
$1,462
(c) Capital expenditures include accruals.
Supplemental Statistics (Unaudited)
Three Months Ended
Year Ended
 
 
Dec. 31

Sept. 30

Dec. 31
Dec. 31

Dec. 31

 
2014

2014

2013
2014

2013

North America E&P - Net Sales Volumes
 
 
 
 
 
Liquid Hydrocarbons (mbbld)
207
197
156
186
149
     Bakken
52
53
38
48
37
     Eagle Ford
107
95
73
91
65
Oklahoma Resource Basins
9
8
6
8
6
     Other North America (e)
39
41
39
39
41
  Crude Oil and Condensate (mbbld)
173
166
132
157
126
     Bakken
49
50
36
45
35
     Eagle Ford
85
75
58
72
51
Oklahoma Resource Basins
3
3
2
3
2
     Other North America (e)
36
38
36
37
38
  Natural Gas Liquids (mbbld)
34
31
24
29
23
     Bakken
3
3
2
3
2
     Eagle Ford
23
20
15
19
14
Oklahoma resource basins
5
5
4
5
4
     Other North America
3
3
3
2
3
  Natural Gas (mmcfd)
331
317
297
310
312
     Bakken
21
18
13
18
13
     Eagle Ford
144
130
100
123
94
Oklahoma Resource Basins
64
63
48
61
48
     Other North America (e)
102
106
136
108
157
Total North America E&P (mboed)
262
250
206
238
201
International E&P - Net Sales Volumes
 
 
 
 
 
Liquid Hydrocarbons (mbbld)
65
39
42
49
73
     Equatorial Guinea
32
27
35
31
34
  United Kingdom
11
6
7
11
15
     Libya
22
6
0
7
24
  Crude Oil and Condensate (mbbld)
55
29
30
39
61
     Equatorial Guinea
22
17
24
21
23
     United Kingdom
11
6
6
11
14
     Libya
22
6
0
7
24
  Natural Gas Liquids (mbbld)
10
10
12
10
12
     Equatorial Guinea
10
10
11
10
11
     United Kingdom
—

—

1
—

—

  Natural Gas (mmcfd)
491
439
490
468
496
     Equatorial Guinea
455
420
455
439
442
     United Kingdom (d)
34
19
28
28
32
     Libya
2
0
7
1
22
Total International E&P (mboed)
147
112
123
127
155
Oil Sands Mining - Net Sales Volumes
 
 
 
 
 
Synthetic Crude Oil (mbbld) (f)
55
55
51
50
48
 
 
 
 
 
 
Total Continuing Operations - Net Sales Volumes (mboed)
464
417
380
415
404
Discontinued Operations - Net Sales Volumes (mboed)(a)
10
58
84
54
89
Total Company - Net Sales Volumes (mboed)
474
475
464
469
493
Net Sales Volumes of Equity Method Investees (mtd)
 
 
 
 
 
     LNG
6,675
6,265
6,282
6,535
6,548
     Methanol
1,131
1,103
1,250
1,092
1,249
(d) Includes natural gas acquired for injection and subsequent resale of 9 mmcfd, 3 mmcfd, 4 mmcfd, 6 mmcfd, and 7 mmcfd in the fourth and third quarters of 2014, the fourth quarter of 2013 and the years 2014 and 2013, respectively.
(e) Includes Gulf of Mexico and other conventional onshore U.S. production, plus Alaska in 2013.
(f) Includes blendstocks.

Supplemental Statistics (Unaudited)
Three Months Ended
Year Ended
 
Dec. 31
Sept. 30
Dec. 31
Dec. 31
Dec. 31
 
2014
2014
2013
2014
2013
North America E&P - Average Price Realizations (g)
 
 
 
 
 
Liquid Hydrocarbons ($ per bbl) (h)
$59.33
$80.89
$79.93
$77.02
$85.20
     Bakken
60.09
82.67
81.61
79.41
87.76
     Eagle Ford
58.88
79.99
80.71
75.83
84.95
Oklahoma Resource Basins
39.48
56.57
51.56
50.86
50.77
Other North America (e)
64.05
85.28
81.28
81.88
88.16
  Crude Oil and Condensate ($ per bbl)
$66.16
$89.65
$87.61
$85.25
$94.19
     Bakken
61.74
85.28
83.70
81.63
90.25
     Eagle Ford
68.63
93.51
92.84
87.99
99.69
Oklahoma Resource Basins
68.82
93.78
94.97
87.15
94.84
Other North America (e)
66.12
87.50
82.86
84.21
90.42
  Natural Gas Liquids ($ per bbl)
$24.80
$33.93
$38.03
$33.42
$35.12
     Bakken
33.79
40.60
45.10
43.25
41.60
     Eagle Ford
22.59
30.90
33.70
29.60
30.16
Oklahoma resource basins
21.65
33.64
36.29
32.61
35.28
Other North America
38.64
51.49
59.62
51.12
55.69
  Natural Gas ($ per mcf)
$3.90
$4.21
$3.76
$4.57
$3.84
     Bakken
4.75
4.29
3.80
5.28
3.90
     Eagle Ford
4.03
4.21
3.57
4.43
3.67
Oklahoma Resource Basins
4.08
3.97
3.74
4.49
3.78
Other North America (e)
3.44
4.34
3.91
4.65
3.95
International E&P- Average Price Realizations
 
 
 
 
 
Liquid Hydrocarbons ($ per bbl)
$61.19
$66.80
$71.11
$68.98
$91.04
     Equatorial Guinea
42.40
51.83
62.60
54.29
60.34
     United Kingdom
58.81
88.68
115.25
93.75
108.92
     Libya
89.18
114.36
0.00
94.70
122.92
  Crude Oil and Condensate ($ per bbl)
$72.13
$89.07
$97.73
$87.23
$108.18
     Equatorial Guinea
61.68
80.85
92.22
81.01
90.62
     United Kingdom
58.89
88.68
117.99
94.31
110.76
     Libya
89.18
114.36
0.00
94.70
122.92
  Natural Gas Liquids ($ per bbl)
$1.28
$1.00
$3.52
$2.46
$5.24
     Equatorial Guinea (i)
1.00
1.00
1.00
1.00
1.00
     United Kingdom
43.80
0.00
73.29
67.73
72.14
  Natural Gas ($ per mcf)
$0.71
$0.56
$0.91
$0.72
$1.15
     Equatorial Guinea (i)
0.24
0.24
0.24
0.24
0.24
     United Kingdom
7.06
7.60
10.21
8.27
10.64
     Libya
0.09
0.00
7.38
3.11
5.44
Oil Sands Mining - Average Price Realizations
 
 
 
 
 
Synthetic Crude Oil ($ per bbl)
$65.56
$88.22
$78.77
$83.35
$87.51
 
 
 
 
 
 
Discontinued Operations - Average Price Realizations ($ per boe)(a)
 
 
 
 
Angola
$0.00
$0.00
$105.43
$99.82
$104.77
Norway
$84.16
$98.62
$110.35
$104.22
$109.60
(g) Excludes gains or losses on derivative instruments.
(h) There were no open crude oil derivative instruments in the third and fourth quarters of 2014. Inclusion of realized gains/losses on crude oil derivative instruments would have increased (decreased) North America E&P average liquid hydrocarbon price realizations per bbl by $0.18 and $(0.27) for fourth quarter and full year 2013.
(i) Represents fixed prices under long-term contracts with Alba Plant LLC, Atlantic Methanol Production Company LLC and/or Equatorial Guinea LNG Holdings Limited, which are equity method investees. Marathon Oil includes its share of income from each of these equity method investees in the International E&P segment.

2014 Estimated Net Proved Reserves
 
North America E&P

International E&P

Oil Sands Mining

Cont. Ops

Disc. Ops

Total

Crude and Condensate (mmbbl)
As of Dec. 31, 2013
497

304

—

801

91

892

Additions
155

8

—

163

3

166

Revisions
36

(4
)
—

32

10

42

Acquisitions
6

—

—

6

—

6

Dispositions
(3
)
—

—

(3
)
(87
)
(90
)
Production
(57
)
(14
)
—

(71
)
(17
)
(88
)
As of Dec. 31, 2014
634

294

—

928

—

928

Natural Gas Liquids (mmbbl)
As of Dec. 31, 2013
119

35

—

154

—

154

Additions
48

—

—

48

—

48

Revisions
4

—

—

4

—

4

Acquisitions
1

—

—

1

—

1

Dispositions
—

—

—

—

—

—

Production
(11
)
(4
)
—

(15
)
—

(15
)
As of Dec. 31, 2014
161

31

—

192

—

192

Natural Gas (bcf)
As of Dec. 31, 2013
1,025

1,553

—

2,578

93

2,671

Additions
290

44

—

334

2

336

Revisions
(24
)
8

—

(16
)
7

(9
)
Acquisitions
5

—

—

5

—

5

Dispositions
(39
)
—

—

(39
)
(89
)
(128
)
Production
(113
)
(169
)
—

(282
)
(13
)
(295
)
As of Dec. 31, 2014
1,144

1,436

—

2,580

—

2,580

Synthetic Crude Oil (mmbbl)
As of Dec. 31, 2013
—

—

680

680

—

680

Additions
—

—

—

—

—

—

Revisions
—

—

(55
)
(55
)
—

(55
)
Acquisitions
—

—

38

38

—

38

Dispositions
—

—

—

—

—

—

Production
—

—

(15
)
(15
)
—

(15
)
As of Dec. 31, 2014
—

—

648

648

—

648

Total Equivalent (mmboe)
As of Dec. 31, 2013
787

598

680

2,065

106

2,171

Additions
252

15

—

267

3

270

Revisions
36

(3
)
(55
)
(22
)
11

(11
)
Acquisitions
8

—

38

46

—

46

Dispositions
(10
)
—

—

(10
)
(101
)
(111
)
Production
(87
)
(46
)
(15
)
(148
)
(19
)
(167
)
As of Dec. 31, 2014
986

564

648

2,198

—

2,198







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