Management's Discussion and Analysis is the company's analysis of its financial performance and of significant trends that may affect future performance. It should be read in conjunction with the financial statements and notes. It contains forward-looking statements including, without limitation, statements relating to the company's plans, strategies, objectives, expectations and intentions that are made pursuant to the "safe harbor" provisions of the Private Securities Litigation Reform Act of 1995. The words "anticipate," "estimate," "believe," "budget," "continue," "could," "intend," "may," "plan," "potential," "predict," "seek," "should," "will," "would," "expect," "objective," "projection," "forecast," "goal," "guidance," "outlook," "effort," "target" and similar expressions identify forward-looking statements. The company does not undertake to update, revise or correct any of the forward-looking information unless required to do so under the federal securities laws. Readers are cautioned that such forward-looking statements should be read in conjunction with the company's disclosures under the heading: "CAUTIONARY STATEMENT FOR THE PURPOSES OF THE 'SAFE HARBOR' PROVISIONS OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995," beginning on page 52.

Due to the separation of our downstream businesses on April 30, 2012, which is reported as discontinued operations, income (loss) from continuing operations is more representative of ConocoPhillips as an independent exploration and production company. The terms "earnings" and "loss" as used in Management's Discussion and Analysis refer to income (loss) from continuing operations.

BUSINESS ENVIRONMENT AND EXECUTIVE OVERVIEW

ConocoPhillips is the world's largest independent exploration and production (E&P) company, based on proved reserves and production of liquids and natural gas. Headquartered in Houston, Texas, we have operations in 30 countries. At June 30, 2012, we had approximately 16,500 employees worldwide and total assets of $114 billion.

The Separation

On April 30, 2012, we completed the separation of our downstream businesses into an independent, publicly traded company, Phillips 66. Our refining, marketing and transportation businesses, most of our Midstream segment, our Chemicals segment, as well as our power generation and certain technology operations included in our Emerging Businesses segment, were transferred to Phillips 66. Results of operations related to Phillips 66 have been classified as discontinued operations in all periods presented in this Form 10-Q. For additional information, see Note 2-Separation of Downstream Business, in the Notes to Consolidated Financial Statements.

Business Environment

As an independent E&P company, we are now solely focused on our core business of exploring for, developing and producing oil and natural gas globally. Our commitment to safety and environmental stewardship, operating excellence and financial responsibility has not changed. As part of our strategic plan, we will continue to focus on improving our financial position and increasing shareholder returns through production and margin growth, portfolio optimization and maintaining sector-leading dividend distributions. In order to remain competitive, we must continually develop and replenish a portfolio of projects which offer attractive financial returns on our investment. We plan to continue to evaluate our assets regularly to determine whether they fit our strategic plans or should be sold or otherwise disposed, and we remain on track to raise $8-$10 billion from noncore asset sales during 2012 and 2013. For the first half of 2012, we have generated proceeds of approximately $1.6 billion as part of this asset disposition program, which mainly included the sale of the Vietnam business and the Alba and Statfjord fields in the North Sea.

Because we participate in a capital-intensive industry, we must often invest significant capital dollars to acquire acreage, explore for new oil and gas fields, develop newly discovered fields and maintain existing fields. We expect our capital spending will be approximately $16 billion in 2012. Over the next five years, we plan to execute a disciplined capital program of approximately $15 billion per year, supporting our reserve replacement target of more than 100 percent. From 2013 forward, we expect to generate 3 to 5 percent annual production volume and margin growth from major development projects already underway in the United States, Canada, United Kingdom and Norwegian North Sea, Malaysia and Australia.

The most significant factors impacting our profitability and related reinvestment of our operating cash flows into our business are the prices for crude oil and natural gas. The prices for these commodity products are subject to factors external to our company, over which we have no control. These prices are supply- and demand-based and can be very volatile; therefore, our strategy is to maintain a core portfolio of low-risk, high-return projects from legacy assets, coupled with a portfolio of projects which offer growth opportunities, such as unconventional plays, deepwater and arctic drilling and liquefied natural gas (LNG).

The following table depicts the average benchmark prices for West Texas Intermediate (WTI) crude oil, Dated Brent crude oil and U.S. Henry Hub natural gas:

                                                                       Dollars Per Unit
                                                        Three Months Ended           Six Months Ended
                                                             June  30                     June 30
                                                           2012          2011          2012          2011

Market Indicators
WTI (per barrel)                                      $   93.44        102.44         98.21         98.21
Dated Brent (per barrel)                                 108.19        117.36        113.34        111.16
U.S. Henry Hub first of month (per million British
thermal units)                                             2.21          4.32          2.47          4.21

Industry crude prices for WTI decreased 9 percent in the second quarter of 2012, compared with the second quarter of 2011, and remained flat in the first six months of 2012, compared with the first six months of 2011, while Brent prices decreased 8 percent in the second quarter of 2012 and increased 2 percent in the first six months of 2012. Global oil prices weakened during the second quarter of 2012, as production expanded and demand eased slightly, largely due to concerns about continued slow economic growth in much of the world and the European sovereign debt crisis. WTI traded at a discount to Brent throughout 2011 and 2012, mainly due to high inventory levels and excess crude supply in the U.S. Midcontinent market.

Henry Hub natural gas prices decreased 49 percent in the second quarter of 2012, compared with the second quarter of 2011, and 41 percent in the first six months of 2012. U.S. natural gas prices remained depressed in 2012, mainly due to high inventory levels, a warmer-than-normal winter and sustained production from shale plays. Prolonged low U.S. natural gas prices could have an adverse effect on our results of operations. The expansion in shale production has also helped boost supplies of natural gas liquids, resulting in downward pressure on natural gas liquids prices in the United States. As a result, our domestic realized natural gas liquids price declined 19 percent in the first half of 2012, compared with the same period of 2011.

Key Operating and Financial Highlights

Significant highlights during the second quarter of 2012 included the following:

• On April 30, 2012, we completed the separation of our downstream businesses, creating two independent energy companies, ConocoPhillips and Phillips 66.

• Achieved production of 1.54 million barrels of oil equivalent per day and generated earnings of $1,755 million in the second quarter of 2012.

• Repurchased 52 million ConocoPhillips shares, representing 4 percent of our outstanding shares.

• Paid a quarterly dividend of 66 cents per share, consistent with pre-separation dividends.

• Initiated exploratory drilling and acquired additional leases in deepwater Gulf of Mexico.

• Progressed the Australia Pacific LNG Project with sanction of the second train in early July 2012.

• Completed the disposition of the Alba and Statfjord fields.

Outlook

Our production for the third quarter of 2012 is estimated to be 1.475 million to 1.525 million barrels of oil equivalent per day (BOED). We expect third-quarter production will be negatively impacted by planned downtime in Alaska and Canada. Our full-year production estimate is now 1.565 million to 1.585 million BOED. Other factors which may impact production include the timing of asset dispositions and the pace of production ramp-up at the Peng Lai fields in Bohai Bay.

RESULTS OF OPERATIONS

Unless otherwise indicated, discussion of results for the three- and six-month periods ended June 30, 2012, is based on a comparison with the corresponding period of 2011.

Consolidated Results

We manage our operations through six operating segments, which are defined by geographic region: Alaska, Lower 48 and Latin America, Canada, Europe, Asia Pacific and Middle East, and Other International. Our LUKOIL Investment represents our prior investment in the ordinary shares of OAO LUKOIL, which was sold in the first quarter of 2011. Corporate and Other represents costs not directly associated with an operating segment, such as most interest expense, corporate overhead, ongoing costs related to the separation and certain technology activities, net of licensing revenues.

A summary of income (loss) from continuing operations by business segment follows:

                                                      Millions of Dollars
                                        Three Months Ended             Six Months Ended
                                             June 30                       June 30
                                          2012           2011           2012           2011

 Alaska                              $     551            492          1,171          1,056
 Lower 48 and Latin America                119            337            374            662
 Canada                                    (94 )          101           (643 )          128
 Europe                                    669            533          1,058            999
 Asia Pacific and Middle East              794            972          2,548          1,848
 Other International                       (19 )           79             67            198
 LUKOIL Investment                           -              -              -            239
 Corporate and Other                      (265 )         (214 )         (579 )         (513 )

 Income from continuing operations   $   1,755          2,300          3,996          4,617

Earnings for ConocoPhillips decreased 24 percent in the second quarter of 2012, while earnings for the six-month period ended June 30, 2012, decreased 13 percent. Lower earnings in the second quarter of 2012 primarily resulted from:

• Lower volumes, largely due to reduced production in China, dispositions and planned downtime.

• Lower prices.

• Higher operating expenses, including an $89 million after-tax charge related to the Bohai Bay settlement.

These items were partially offset by:

• Higher gains from asset sales of $281 million after-tax, compared with gains of $27 million after-tax in the second quarter of 2011.

• Lower production taxes and depreciation, depletion and amortization (DD&A) expenses, mainly as a result of lower volumes.

The decrease in earnings for the six-month period of 2012 was primarily due to:

• Lower volumes, largely due to reduced production in China, dispositions and planned downtime.

• Higher impairments. Non-cash impairments for the six-month period of 2012 totaled $550 million after-tax.

• Lower natural gas prices.

• Higher operating expenses, which included the $89 million after-tax charge related to the Bohai Bay settlement and $73 million of after-tax separation costs.

These items were partially offset by:

• Higher gains from asset sales of $1,220 million after-tax, compared with gains of $419 million after-tax in the comparative period of 2011.

• Lower DD&A expenses, mainly as a result of lower volumes.

• Higher crude oil and LNG prices.

See the "Segment Results" section for additional information on our segment results.

Income Statement Analysis

Sales and other operating revenues for the second quarter and six-month period of 2012 decreased 19 percent and 12 percent, respectively, mainly due to lower crude oil, natural gas and LNG volumes and lower natural gas prices. Lower crude oil prices also contributed to the decrease in the second quarter of 2012.

Equity in earnings of affiliates for the second quarter and six-month period of 2012 increased 41 percent and 45 percent, respectively. The increases in both periods primarily resulted from:

• Improved earnings from Qatar Liquefied Gas Company Limited (3) (QG3), primarily due to higher LNG prices and a $72 million tax-related adjustment.

• The absence of the $83 million before-tax write-off of our investment associated with the cancellation of the Denali gas pipeline project in the second quarter of 2011.

These increases in equity earnings were partially offset by lower earnings from Naryanmarneftegaz (NMNG), largely due to lower volumes. Additionally, FCCL Partnership experienced lower earnings in the second quarter of 2012, primarily as a result of lower bitumen prices, partially offset by higher volumes.

Gain on dispositions for the second quarter and six-month period of 2012 were $583 million and $1,523 million, respectively, compared with gains of $35 million and $648 million for the respective periods in 2011. Gains realized in both periods of 2012 included the disposition of our Statfjord and Alba fields located in the North Sea. Additionally, gains realized in the six-month period of 2012 mainly included the disposition of our Vietnam business, partially offset by the sale of certain E&P assets located in the Lower 48 and the remaining divestiture of our LUKOIL shares in the six-month period of 2011.

Purchased commodities decreased 25 percent and 19 percent in the second quarter and six-month period of 2012, respectively, largely as a result of lower U.S. natural gas prices, partly offset by higher purchased volumes.

Production and operating expenses increased 18 percent in the second quarter and 11 percent in the six-month period of 2012, mostly due to increased operating expenses in China and planned downtime at our Bayu-Undan Field and Darwin LNG facility.

Selling, general and administrative expenses increased 16 percent and 25 percent in the second quarter and six-month period of 2012, mainly as a result of ongoing costs associated with the separation of Phillips 66.

Exploration expenses increased $509 million in the six-month period of 2012. The increase was mostly due to the impairment of undeveloped leasehold costs associated with the Mackenzie Gas Project as a result of the indefinite suspension of the project in the first quarter of 2012.

DD&A decreased 12 percent in both the second quarter and six-month period of 2012. The decreases were mainly due to lower production volumes as a result of asset dispositions and lower production in China, partially offset by higher production volumes in the Lower 48.

Impairments for the second quarter of 2012 increased $82 million, primarily due to an increase in the asset retirement obligation for the Don Field in the United Kingdom, which has ceased production. Impairments in the six-month period of 2012 increased $296 million, mainly due to the $213 million impairment of capitalized project development costs associated with the Mackenzie Gas Project in the first quarter of 2012, as well as the Don Field impairment.

Taxes other than income taxes decreased 24 percent in the second quarter 2012, primarily due to lower production taxes as a result of lower crude oil prices and volumes.

Interest and debt expense for the second quarter and six-month period of 2012 decreased 19 percent and 22 percent, respectively, primarily due to higher capitalized interest on projects and lower interest expense due to lower debt levels.

See Note 21-Income Taxes, in the Notes to Consolidated Financial Statements, for information regarding our provision for income taxes and effective tax rate.

Summary Operating Statistics




                                                        Three Months Ended           Six Months Ended
                                                             June  30                     June 30
                                                           2012          2011          2012          2011

Average Net Production
Crude oil (MBD)*                                            608           668           629           692
Natural gas liquids (MBD)                                   154           146           160           145
Bitumen (MBD)                                                88            67            86            66
Natural gas (MMCFD)**                                     4,153         4,552         4,287         4,611


Total Production (MBOED)***                               1,542         1,640         1,590         1,672


                                                                        Dollars Per Unit
Average Sales Prices
Crude oil (per barrel)                                $  105.56        112.95        108.95        105.42
Natural gas liquids (per barrel)                          43.55         56.88         48.90         54.62
Bitumen (per barrel)                                      51.38         65.74         55.89         60.44
Natural gas (per thousand cubic feet)                      4.41          5.50          4.61          5.36

                                                                       Millions of Dollars
Exploration Expenses
General administrative; geological and geophysical;
and lease rentals                                     $     154           175           315           301
Leasehold impairment                                         52            41           564            82
Dry holes                                                    64            48            70            57

                                                      $     270           264           949           440

*Thousands of barrels per day.

**Millions of cubic feet per day. Represents quantities available for sale and excludes gas equivalent of natural gas liquids included above.

***Thousands of barrels of oil equivalent per day.

We explore for, produce, transport and market crude oil, bitumen, natural gas, LNG and natural gas liquids on a worldwide basis. At June 30, 2012, our operations were producing in the United States, Norway, the United Kingdom, Canada, Australia, offshore Timor-Leste in the Timor Sea, Indonesia, China, Libya, Nigeria, Algeria, Qatar and Russia.

Total production averaged 1,542 MBOED in the second quarter of 2012, a decrease of 6 percent compared with the second quarter of 2011. Production for the six-month period of 2012 averaged 1,590 MBOED, down 5 percent from the corresponding period of 2011. The decreases in both periods of 2012 primarily resulted from normal field decline, dispositions, reduced production in China and natural gas curtailments in North America. In addition, higher downtime in the second quarter of 2012 contributed to the decrease in production. These decreases were partly offset by additional production from major projects, mainly from FCCL and shale plays in the Lower 48, the ramp-up of activity in Libya following a period of civil unrest in 2011, and increased drilling programs.

Segment Results

Alaska




                                                            Three Months Ended           Six Months Ended
                                                                 June  30                     June 30
                                                               2012          2011          2012          2011

Income from Continuing Operations (millions of dollars)   $     551           492         1,171         1,056


Average Net Production
Crude oil (MBD)                                                 190           207           199           203
Natural gas liquids (MBD)                                        16            16            17            16
Natural gas (MMCFD)                                              56            62            57            65


Total Production (MBOED)                                        215           233           226           230


Average Sales Prices
Crude oil (dollars per barrel)                            $  112.38        113.75        112.28        104.26
Natural gas (dollars per thousand cubic feet)                  3.93          4.66          4.31          4.28

The Alaska segment primarily explores for, produces, transports and markets crude oil, natural gas liquids, natural gas and LNG. As of June 30, 2012, Alaska contributed 25 percent of our worldwide liquids production and 1 percent of our natural gas production.

Our Alaska operations reported earnings of $551 million in the second quarter of 2012, a 12 percent increase compared with the same period in 2011. Earnings for the six-month period of 2012 were $1,171 million, an 11 percent increase compared with the same period in 2011. Earnings in both the second quarter and six-month period of 2012 benefitted from additional sales of LNG, in addition to the absence of the $54 million after-tax impairment of our investment associated with the cancellation of the Denali gas pipeline project in the second quarter of 2011. In addition, second quarter 2012 earnings improved due to lower production taxes, mainly as a result of lower crude oil production. These increases were partially offset by lower crude oil volumes and higher operating expenses. Earnings in the six-month period of 2012 increased primarily as a result of higher crude oil prices and lower DD&A, partially offset by increased production taxes, lower crude oil volumes and higher operating expenses.

Production averaged 215 MBOED in the second quarter of 2012, a decrease of 8 percent compared with the second quarter of 2011. Production for the six-month period of 2012 was 226 MBOED, a 2 percent decrease compared with the corresponding period in 2011. The decreases in both periods of 2012 were mainly due to normal field decline, partly offset by increased drilling activity on the Western North Slope. Additionally, the six-month period of 2012 experienced less unplanned downtime.

Lower 48 and Latin America




                                                            Three Months Ended           Six Months Ended
                                                                 June  30                    June  30
                                                               2012          2011          2012          2011

Income from Continuing Operations (millions of dollars)   $     119           337           374           662


Average Net Production
Crude oil (MBD)                                                 115            88           116            86
Natural gas liquids (MBD)                                        83            72            83            69
Natural gas (MMCFD)                                           1,456         1,589         1,479         1,556


Total Production (MBOED)                                        441           425           446           414


Average Sales Prices
Crude oil (dollars per barrel)                            $   89.61         99.70         94.34         94.05
Natural gas liquids (dollars per barrel)                      34.62         51.45         39.79         48.82
Natural gas (dollars per thousand cubic feet)                  2.10          4.22          2.38          4.16

As of June 30, 2012, Lower 48 and Latin America contributed 23 percent of our worldwide liquids production and 34 percent of our natural gas production. The Lower 48 and Latin America segment primarily consists of operations located in the U.S. Lower 48 states. Also included in this segment is our 39 percent equity interest in Phoenix Park Gas Processors Limited, which processes natural gas in Trinidad and markets natural gas liquids in the Atlantic Basin, and the Wingate fractionation plant located in Gallup, New Mexico.

Lower 48 and Latin America operations reported earnings of $119 million in the second quarter of 2012, a 65 percent decrease compared with the same period in 2011. Earnings for the six-month period of 2012 were $374 million, a 44 percent decrease compared with the same period in 2011. The decreases for both periods of 2012 were primarily the result of lower natural gas and natural gas liquids prices, higher DD&A and operating expenses, partially offset by higher crude oil and natural gas liquids volumes. Lower gains from asset dispositions also contributed to the decrease in earnings for the six-month period of 2012.

Lower 48 production averaged 441 MBOED in the second quarter of 2012, a 4 percent increase compared with the second quarter of 2011. Production for the six-month period of 2012 was 446 MBOED, an 8 percent increase compared with the same period in 2011. The increases in both periods of 2012 were mainly due to new production, primarily from the Eagle Ford, Bakken and Permian areas, and improved drilling and well performance, partially offset by normal field decline. The six-month period of 2012 also experienced higher unplanned downtime.

Canada




                                                        Three Months Ended            Six Months Ended
. . .