10-Q 1 d164470d10q.htm 10-Q 10-Q
Table of Contents

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

FORM 10-Q

 

 

(Mark One)

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2016

or

 

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from              to             

Commission file number: 001-32395

 

 

ConocoPhillips

(Exact name of registrant as specified in its charter)

 

 

 

Delaware   01-0562944

(State or other jurisdiction of

incorporation or organization)

 

(I.R.S. Employer

Identification No.)

600 North Dairy Ashford, Houston, TX 77079

(Address of principal executive offices) (Zip Code)

281-293-1000

(Registrant’s telephone number, including area code)

 

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  x    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  x    No  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

 

Large accelerated filer   x    Accelerated filer   ¨
Non-accelerated filer   ¨    Smaller reporting company   ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  x

The registrant had 1,238,505,159 shares of common stock, $.01 par value, outstanding at June 30, 2016.

 

 

 


Table of Contents

CONOCOPHILLIPS

TABLE OF CONTENTS

 

     Page  

Part I—Financial Information

  

Item 1. Financial Statements

  

Consolidated Income Statement

     1   

Consolidated Statement of Comprehensive Income

     2   

Consolidated Balance Sheet

     3   

Consolidated Statement of Cash Flows

     4   

Notes to Consolidated Financial Statements

     5   

Supplementary Information—Condensed Consolidating Financial Information

     25   

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

     30   

Item 3. Quantitative and Qualitative Disclosures About Market Risk

     50   

Item 4. Controls and Procedures

     50   

Part II—Other Information

  

Item 1. Legal Proceedings

     51   

Item 1A. Risk Factors

     51   

Item 6. Exhibits

     52   

Signature

     53   


Table of Contents

PART I. FINANCIAL INFORMATION

Item 1. FINANCIAL STATEMENTS

 

              
Consolidated Income Statement      ConocoPhillips   

 

                                                           
     Millions of Dollars  
     Three Months Ended
June 30
    Six Months Ended
June 30
 
     2016     2015     2016     2015  
  

 

 

   

 

 

 

Revenues and Other Income

        

Sales and other operating revenues

   $ 5,348        8,293        10,469        16,009   

Equity in earnings (losses) of affiliates

     80        258        (69     463   

Gain on dispositions

     128        52        151        104   

Other income

     19        57        39        86   

 

 

Total Revenues and Other Income

     5,575        8,660        10,590        16,662   

 

 

Costs and Expenses

        

Purchased commodities

     2,002        3,230        4,227        6,467   

Production and operating expenses

     1,445        1,798        2,799        3,600   

Selling, general and administrative expenses

     167        218        353        377   

Exploration expenses

     610        549        1,115        1,031   

Depreciation, depletion and amortization

     2,329        2,329        4,576        4,460   

Impairments

     62        78        198        94   

Taxes other than income taxes

     197        225        377        449   

Accretion on discounted liabilities

     112        122        221        243   

Interest and debt expense

     312        210        593        412   

Foreign currency transaction gains

     (17     (8     (1     (24

 

 

Total Costs and Expenses

     7,219        8,751        14,458        17,109   

 

 

Loss before income taxes

     (1,644     (91     (3,868     (447

Income tax provision (benefit)

     (586     73        (1,354     (569

 

 

Net income (loss)

     (1,058     (164     (2,514     122   

Less: net income attributable to noncontrolling interests

     (13     (15     (26     (29

 

 

Net Income (Loss) Attributable to ConocoPhillips

   $ (1,071     (179     (2,540     93   

 

 

Net Income (Loss) Attributable to ConocoPhillips Per Share of Common Stock (dollars)

        

Basic

   $ (0.86     (0.15     (2.04     0.07   

Diluted

     (0.86     (0.15     (2.04     0.07   

 

 

Dividends Paid Per Share of Common Stock (dollars)

   $ 0.25        0.73        0.50        1.46   

 

 

Average Common Shares Outstanding (in thousands)

        

Basic

     1,244,892        1,241,026        1,244,724        1,240,909   

Diluted

     1,244,892        1,241,026        1,244,724        1,246,130   

 

 

See Notes to Consolidated Financial Statements.

 

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Table of Contents
Consolidated Statement of Comprehensive Income      ConocoPhillips   

 

                                                           
     Millions of Dollars  
     Three Months Ended
June 30
    Six Months Ended
June 30
 
     2016     2015     2016     2015  
  

 

 

   

 

 

 

Net Income (Loss)

   $ (1,058     (164     (2,514     122   

Other comprehensive income (loss)

        

Defined benefit plans

        

Prior service credit arising during the period

            140               140   

Reclassification adjustment for amortization of prior service credit included in net loss

     (9     (3     (18     (4

Net actuarial gain (loss) arising during the period

     (69     15        (300     15   

Reclassification adjustment for amortization of net actuarial losses included in net income

     74        102        182        152   

Income taxes on defined benefit plans

     3        (93     53        (110

 

 

Defined benefit plans, net of tax

     (1     161        (83     193   

 

 

Foreign currency translation adjustments

     (224     796        959        (1,949

Income taxes on foreign currency translation adjustments

            (9            17   

 

 

Foreign currency translation adjustments, net of tax

     (224     787        959        (1,932

 

 

Other Comprehensive Income (Loss), Net of Tax

     (225     948        876        (1,739

 

 

Comprehensive Income (Loss)

     (1,283     784        (1,638     (1,617

Less: comprehensive income attributable to noncontrolling interests

     (13     (15     (26     (29

 

 

Comprehensive Income (Loss) Attributable to ConocoPhillips

   $ (1,296     769        (1,664     (1,646

 

 

See Notes to Consolidated Financial Statements.

 

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Consolidated Balance Sheet      ConocoPhillips   

 

                             
     Millions of Dollars  
     June 30     December 31  
     2016     2015  
  

 

 

 

Assets

    

Cash and cash equivalents

   $ 2,863        2,368   

Short-term investments

     1,289          

Accounts and notes receivable (net of allowance of $5 million in 2016 and $7 million in 2015)

     3,144        4,314   

Accounts and notes receivable—related parties

     172        200   

Inventories

     1,150        1,124   

Prepaid expenses and other current assets

     641        783   

 

 

Total Current Assets

     9,259        8,789   

Investments and long-term receivables

     21,385        20,490   

Loans and advances—related parties

     639        696   

Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $74,243 million in 2016 and $70,413 million in 2015)

     63,685        66,446   

Other assets

     1,086        1,063   

 

 

Total Assets

   $ 96,054        97,484   

 

 

Liabilities

    

Accounts payable

   $ 3,746        4,895   

Accounts payable—related parties

     72        38   

Short-term debt

     1,331        1,427   

Accrued income and other taxes

     554        499   

Employee benefit obligations

     538        887   

Other accruals

     1,107        1,510   

 

 

Total Current Liabilities

     7,348        9,256   

Long-term debt

     27,346        23,453   

Asset retirement obligations and accrued environmental costs

     9,820        9,580   

Deferred income taxes

     9,655        10,999   

Employee benefit obligations

     2,533        2,286   

Other liabilities and deferred credits

     1,521        1,828   

 

 

Total Liabilities

     58,223        57,402   

 

 

Equity

    

Common stock (2,500,000,000 shares authorized at $.01 par value)

    

Issued (2016—1,780,735,832 shares; 2015—1,778,226,388 shares)

    

Par value

     18        18   

Capital in excess of par

     46,429        46,357   

Treasury stock (at cost: 2016—542,230,673 shares; 2015—542,230,673 shares)

     (36,780     (36,780

Accumulated other comprehensive loss

     (5,371     (6,247

Retained earnings

     33,248        36,414   

 

 

Total Common Stockholders’ Equity

     37,544        39,762   

Noncontrolling interests

     287        320   

 

 

Total Equity

     37,831        40,082   

 

 

Total Liabilities and Equity

   $ 96,054        97,484   

 

 

See Notes to Consolidated Financial Statements.

 

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Table of Contents
Consolidated Statement of Cash Flows      ConocoPhillips   

 

                             
     Millions of Dollars  
     Six Months Ended
June 30
 
     2016     2015  
  

 

 

 

Cash Flows From Operating Activities

    

Net income (loss)

   $ (2,514     122   

Adjustments to reconcile net income (loss) to net cash provided by operating activities

    

Depreciation, depletion and amortization

     4,576        4,460   

Impairments

     198        94   

Dry hole costs and leasehold impairments

     823        713   

Accretion on discounted liabilities

     221        243   

Deferred taxes

     (1,457     (602

Distributions received greater than equity losses (undistributed equity earnings)

     222        (41

Gain on dispositions

     (151     (104

Other

     (17     (454

Working capital adjustments

    

Decrease in accounts and notes receivable

     1,097        1,419   

Decrease (increase) in inventories

     (23     42   

Decrease (increase) in prepaid expenses and other current assets

     (51     153   

Decrease in accounts payable

     (454     (1,358

Decrease in taxes and other accruals

     (790     (645

 

 

Net Cash Provided by Operating Activities

     1,680        4,042   

 

 

Cash Flows From Investing Activities

    

Capital expenditures and investments

     (2,954     (5,739

Working capital changes associated with investing activities

     (363     (678

Proceeds from asset dispositions

     363        294   

Net purchases of short-term investments

     (1,292       

Collection of advances/loans—related parties

     53        52   

Other

     6        291   

 

 

Net Cash Used in Investing Activities

     (4,187     (5,780

 

 

Cash Flows From Financing Activities

    

Issuance of debt

     4,594        2,498   

Repayment of debt

     (827     (62

Issuance of company common stock

     (45     (46

Dividends paid

     (626     (1,819

Other

     (79     (35

 

 

Net Cash Provided by Financing Activities

     3,017        536   

 

 

Effect of Exchange Rate Changes on Cash and Cash Equivalents

     (15     (47

 

 

Net Change in Cash and Cash Equivalents

     495        (1,249

Cash and cash equivalents at beginning of period

     2,368        5,062   

 

 

Cash and Cash Equivalents at End of Period

   $ 2,863        3,813   

 

 

See Notes to Consolidated Financial Statements.

 

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Notes to Consolidated Financial Statements      ConocoPhillips   

Note 1—Basis of Presentation

The interim-period financial information presented in the financial statements included in this report is unaudited and, in the opinion of management, includes all known accruals and adjustments necessary for a fair presentation of the consolidated financial position of ConocoPhillips and its results of operations and cash flows for such periods. All such adjustments are of a normal and recurring nature unless otherwise disclosed. Certain notes and other information have been condensed or omitted from the interim financial statements included in this report. Therefore, these financial statements should be read in conjunction with the consolidated financial statements and notes included in our 2015 Annual Report on Form 10-K.

Effective November 1, 2015, the Other International and historically presented Europe segments were restructured to align with changes to our internal organization structure. The Libya business was moved from the Other International segment to the historically presented Europe segment, which is now renamed Europe and North Africa. Certain financial information has been revised for all prior periods presented to reflect the change in the composition of our operating segments. For additional information, see Note 19—Segment Disclosures and Related Information.

Note 2—Change in Accounting Principles

We adopted the provisions of Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) No. 2015-02, “Amendments to the Consolidation Analysis,” beginning January 1, 2016. The ASU amends existing requirements applicable to reporting entities that are required to evaluate whether certain legal entities, including variable interest entities (VIEs), should be consolidated. The adoption of this ASU did not have an impact on our consolidated financial statements and disclosures. See Note 3—Variable Interest Entities, for additional information on our significant VIE.

Note 3—Variable Interest Entities

We hold variable interests in VIEs that have not been consolidated because we are not considered the primary beneficiary. Information on our significant VIE follows:

Australia Pacific LNG Pty Ltd (APLNG)

APLNG is considered a VIE, as it has entered into certain contractual arrangements that provide it with additional forms of subordinated financial support. We are not the primary beneficiary of APLNG because we share with Origin Energy and China Petrochemical Corporation (Sinopec) the power to direct the key activities of APLNG that most significantly impact its economic performance, which involve activities related to the production and commercialization of coalbed methane, as well as liquefied natural gas (LNG) processing and export marketing. As a result, we do not consolidate APLNG, and it is accounted for as an equity method investment.

As of June 30, 2016, we have not provided any financial support to APLNG other than amounts previously contractually required. Unless we elect otherwise, we have no requirement to provide liquidity or purchase the assets of APLNG. See Note 6—Investments, Loans and Long-Term Receivables, and Note 11—Guarantees, for additional information.

 

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Note 4—Inventories

Inventories consisted of the following:

 

                             
     Millions of Dollars  
     June 30      December 31  
     2016      2015  
  

 

 

 

Crude oil and natural gas

   $ 463         406   

Materials and supplies

     687         718   

 

 
   $ 1,150         1,124   

 

 

Inventories valued on the last-in, first-out (LIFO) basis totaled $331 million and $317 million at June 30, 2016 and December 31, 2015, respectively. The estimated excess of current replacement cost over LIFO cost of inventories was approximately $74 million and $6 million at June 30, 2016 and December 31, 2015, respectively.

Note 5—Assets Held for Sale or Sold

On April 22, 2016, we sold our interest in the Alaska Beluga River Unit natural gas field in the Cook Inlet for $134 million, net of settlement of gas imbalances and customary adjustments, and recognized a gain on disposition of $56 million. At the time of disposition, the net carrying value of our Beluga River Unit interest, which is included in the Alaska segment, was $78 million, consisting primarily of $100 million of properties, plants and equipment (PP&E) and $19 million of asset retirement obligations (ARO).

Note 6—Investments, Loans and Long-Term Receivables

APLNG

APLNG’s $8.5 billion project finance facility consists of financing agreements executed by APLNG with the Export-Import Bank of the United States for approximately $2.9 billion, the Export-Import Bank of China for approximately $2.7 billion, and a syndicate of Australian and international commercial banks for approximately $2.9 billion. At June 30, 2016, $8.5 billion had been drawn from the facility. In connection with the execution of the project financing, we provided a completion guarantee for our pro-rata share of the project finance facility until the project achieves financial completion. See Note 11—Guarantees, for additional information.

APLNG is considered a VIE, as it has entered into certain contractual arrangements that provide it with additional forms of subordinated financial support. See Note 3—Variable Interest Entities, for additional information.

Following the fourth-quarter 2015 impairment of our investment in APLNG, the outlook for crude oil and natural gas prices continued to deteriorate into the first quarter of 2016. As a result, the estimated fair value of our investment in APLNG declined to an amount below book value as of March 31, 2016. Based on a review of the facts and circumstances surrounding this decline in fair value, we concluded the impairment was not other than temporary under the guidance of FASB Accounting Standards Codification (ASC) Topic 323, “Investments – Equity Method and Joint Ventures.” During the second quarter of 2016, primarily due to an improved outlook for crude oil prices, the estimated fair value of our investment increased and is above book value as of June 30, 2016.

At June 30, 2016, the book value of our equity method investment in APLNG was $10,327 million. The balance is included in the “Investments and long-term receivables” line on our consolidated balance sheet.

 

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FCCL

At June 30, 2016, the book value of our equity method investment in FCCL Partnership was $8,939 million, net of a $1,363 million reduction due to cumulative foreign currency translation effects. The balance is included in the “Investments and long-term receivables” line on our consolidated balance sheet.

Loans and Long-Term Receivables

As part of our normal ongoing business operations, and consistent with industry practice, we enter into numerous agreements with other parties to pursue business opportunities. Included in such activity are loans made to certain affiliated and non-affiliated companies. At June 30, 2016, significant loans to affiliated companies included $750 million in project financing to Qatar Liquefied Gas Company Limited (3) (QG3).

The long-term portion of these loans is included in the “Loans and advances—related parties” line on our consolidated balance sheet, while the short-term portion is in “Accounts and notes receivable—related parties.”

Note 7—Suspended Wells

The capitalized cost of suspended wells at June 30, 2016, was $1,293 million, an increase of $33 million from $1,260 million at year-end 2015. Two suspended wells in the Gulf of Mexico totaling $100 million were charged to dry hole expense during the first six months of 2016 relating to exploratory well costs capitalized for a period greater than one year as of December 31, 2015.

Note 8—Impairments

During the three- and six-month periods ended June 30, 2016 and 2015, we recognized before-tax impairment charges within the following segments:

 

                                                           
     Millions of Dollars  
     Three Months Ended
June 30
     Six Months Ended
June 30
 
     2016      2015      2016      2015  
  

 

 

    

 

 

 

Alaska

   $         7                 7   

Lower 48

     51                 60           

Europe and North Africa

     10         71         137         87   

Asia Pacific and Middle East

     1                 1           

 

 
   $ 62         78         198         94   

 

 

Our Europe and North Africa segment included impairments of $137 million in the six-month period of 2016, primarily as a result of lower natural gas prices in the United Kingdom. Our Lower 48 segment included impairments of $51 million and $60 million respectively, in the three- and six-month periods of 2016, primarily as a result of lower natural gas prices and increased asset retirement obligation estimates.

The three- and six-month periods of 2015 included impairments in our Europe and North Africa segment of $71 million and $87 million, respectively, primarily as a result of lower natural gas prices in the United Kingdom.

The charges discussed below are included in the “Exploration expenses” line on our consolidated income statement and are not reflected in the table above.

Exploration expenses in the three- and six-month periods of 2016 are aligned with our decision announced in 2015 to reduce deepwater exploration spending. We recorded a $203 million before-tax impairment for the

 

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associated carrying value of our Gibson and Tiber undeveloped leaseholds in deepwater Gulf of Mexico in the second quarter of 2016. Additionally, in the first quarter of 2016, we recorded a $95 million before-tax impairment for the associated carrying value of capitalized undeveloped leasehold costs of the Melmar prospect, and a $73 million impairment in our Lower 48 segment, primarily as a result of changes in the estimated market value following the completion of an initial marketing effort.

Note 9—Debt

In the first quarter of 2016, we reduced our revolving credit facility, expiring in June 2019, from $7.0 billion to $6.75 billion. We have two commercial paper programs supported by our $6.75 billion revolving credit facility: the ConocoPhillips $6.25 billion program, primarily a funding source for short-term working capital needs, and the ConocoPhillips Qatar Funding Ltd. $500 million program, which is used to fund commitments relating to QG3. Commercial paper maturities are generally limited to 90 days.

At June 30, 2016 and December 31, 2015, we had no direct outstanding borrowings under the revolving credit facility, with no letters of credit as of June 30, 2016 or December 31, 2015. Under the ConocoPhillips Qatar Funding Ltd. commercial paper program, no commercial paper was outstanding at June 30, 2016, compared with $803 million at December 31, 2015. Since we had no commercial paper outstanding and had issued no letters of credit, we had access to $6.75 billion in borrowing capacity under our revolving credit facility at June 30, 2016.

In March 2016, we issued notes consisting of:

 

   

The $1,250 million of 4.20% Notes due 2021.

   

The $1,250 million of 4.95% Notes due 2026.

   

The $500 million of 5.95% Notes due 2046.

In addition, on March 18, 2016, we entered into a $1,600 million three-year senior unsecured term loan facility. Borrowings will accrue interest at a base rate or, for certain Eurodollar borrowings, the London Interbank Offered Rate (LIBOR), in each case plus a margin that is set based on our corporate credit ratings. The applicable margin for loans bearing interest based on the base rate ranges from 0.50% to 1.00% and the applicable margin for loans bearing interest based on LIBOR ranges from 1.50% to 2.00%. Based on our current corporate credit ratings, the applicable margin for loans accruing interest at the base rate is 0.50% and the applicable margin for loans accruing interest at LIBOR is 1.50%.

The term loan facility contains customary covenants regarding, among other matters, material compliance with laws and restrictions against certain consolidations, mergers and asset sales and creation of certain liens on our assets and consolidated subsidiaries. The term loan facility also contains financial covenants including a total debt to capitalization ratio, excluding the impacts of certain noncash impairments and foreign currency translation adjustments as defined in the Term Loan Agreement, which may not exceed 65 percent. At June 30, 2016, we were in compliance with this covenant.

The term loan facility includes customary events of default (subject to specified cure periods, materiality qualifiers and exceptions), including the failure to pay any interest, principal or fees when due, the failure to perform or the violation of any covenant contained in the term loan facility, the making of materially inaccurate or false representations or warranties, a default on certain material indebtedness, insolvency or bankruptcy, a change of control and the occurrence of material Employee Retirement Income Security Act of 1974 (ERISA) events and certain judgments against us or our material subsidiaries.

We have the right at any time and from time to time to prepay the term loan, in whole or in part, without premium or penalty upon notice to the Administrative Agent.

The net proceeds of the notes and term loan will be used for general corporate purposes.

 

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At June 30, 2016, we had $283 million of certain variable rate demand bonds (VRDBs) outstanding with maturities ranging through 2035. The VRDBs are redeemable at the option of the bondholders on any business day. The VRDBs are included in the “Long-term debt” line on our consolidated balance sheet.

Note 10—Noncontrolling Interests

Activity attributable to common stockholders’ equity and noncontrolling interests for the first six months of 2016 and 2015 was as follows:

 

                                                                                         
     Millions of Dollars  
     2016     2015  
    

Common

Stockholders’

Equity

   

Non-

Controlling

Interest

   

Total

Equity

   

Common

Stockholders’

Equity

   

Non-

Controlling

Interest

   

Total

Equity

 
  

 

 

   

 

 

 

Balance at January 1

   $ 39,762        320        40,082        51,911        362        52,273   

Net income (loss)

     (2,540     26        (2,514     93        29        122   

Dividends

     (626            (626     (1,819            (1,819

Distributions to noncontrolling interests

            (59     (59            (43     (43

Other changes, net*

     948               948        (1,565     1        (1,564

 

 

Balance at June 30

   $ 37,544        287        37,831        48,620        349        48,969   

 

 

*Includes components of other comprehensive income (loss), which are disclosed separately in the Consolidated Statement of Comprehensive Income.

Note 11—Guarantees

At June 30, 2016, we were liable for certain contingent obligations under various contractual arrangements as described below. We recognize a liability, at inception, for the fair value of our obligation as a guarantor for newly issued or modified guarantees. Unless the carrying amount of the liability is noted below, we have not recognized a liability because the fair value of the obligation is immaterial. In addition, unless otherwise stated, we are not currently performing with any significance under the guarantee and expect future performance to be either immaterial or have only a remote chance of occurrence.

APLNG Guarantees

At June 30, 2016, we had outstanding multiple guarantees in connection with our 37.5 percent ownership interest in APLNG. The following is a description of the guarantees with values calculated utilizing June 2016 exchange rates:

 

   

We have guaranteed APLNG’s performance with regard to a construction contract executed in connection with APLNG’s issuance of the Train 1 and Train 2 Notices to Proceed. We estimate the remaining term of this guarantee is one year. Our maximum potential amount of future payments related to this guarantee is approximately $80 million and would become payable if APLNG cancels the applicable construction contract and does not perform with respect to the amounts owed to the contractor.

 

   

We have issued a construction completion guarantee related to the third-party project financing secured by APLNG. Our maximum potential amount of future payments under the guarantee is estimated to be $3.2 billion, which could be payable if the full debt financing capacity is utilized and completion of the project is not achieved. Our guarantee of the project financing will be released upon meeting certain completion tests with milestones, which we estimate should occur beginning

 

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later in 2016. Our maximum exposure at June 30, 2016, is $3.2 billion based upon our pro-rata share of the facility used at that date. At June 30, 2016, the carrying value of this guarantee is approximately $114 million.

 

   

In conjunction with our original purchase of an ownership interest in APLNG from Origin Energy in October 2008, we agreed to reimburse Origin Energy for our share of the existing contingent liability arising under guarantees of an existing obligation of APLNG to deliver natural gas under several sales agreements with remaining terms of 1 to 26 years. Our maximum potential liability for future payments, or cost of volume delivery, under these guarantees is estimated to be $1.0 billion ($1.9 billion in the event of intentional or reckless breach), and would become payable if APLNG fails to meet its obligations under these agreements and the obligations cannot otherwise be mitigated. Future payments are considered unlikely, as the payments, or cost of volume delivery, would only be triggered if APLNG does not have enough natural gas to meet these sales commitments and if the co-venturers do not make necessary equity contributions into APLNG.

 

   

We have guaranteed the performance of APLNG with regard to certain other contracts executed in connection with the project’s continued development. The guarantees have remaining terms of up to 29 years or the life of the venture. Our maximum potential amount of future payments related to these guarantees is approximately $160 million and would become payable if APLNG does not perform.

Other Guarantees

We have other guarantees with maximum future potential payment amounts totaling approximately $530 million, which consist primarily of a guarantee of the residual value of a leased office building, guarantees of the residual value of leased corporate aircraft, a guarantee for our portion of a joint venture’s project finance reserve accounts, and a guarantee of minimum charter revenue for an LNG vessel. These guarantees have remaining terms of up to eight years and would become payable if, upon sale, certain asset values are lower than guaranteed amounts, business conditions decline at guaranteed entities, or as a result of nonperformance of contractual terms by guaranteed parties.

Indemnifications

Over the years, we have entered into agreements to sell ownership interests in certain corporations, joint ventures and assets that gave rise to qualifying indemnifications. These agreements include indemnifications for taxes, environmental liabilities, employee claims and litigation. The terms of these indemnifications vary greatly. The majority of these indemnifications are related to environmental issues, the term is generally indefinite and the maximum amount of future payments is generally unlimited. The carrying amount recorded for these indemnifications at June 30, 2016, was approximately $90 million. We amortize the indemnification liability over the relevant time period, if one exists, based on the facts and circumstances surrounding each type of indemnity. In cases where the indemnification term is indefinite, we will reverse the liability when we have information the liability is essentially relieved or amortize the liability over an appropriate time period as the fair value of our indemnification exposure declines. Although it is reasonably possible future payments may exceed amounts recorded, due to the nature of the indemnifications, it is not possible to make a reasonable estimate of the maximum potential amount of future payments. Included in the recorded carrying amount at June 30, 2016, were approximately $40 million of environmental accruals for known contamination that are included in the “Asset retirement obligations and accrued environmental costs” line on our consolidated balance sheet. For additional information about environmental liabilities, see Note 12—Contingencies and Commitments.

On March 1, 2015, a supplier to one of the refineries included in Phillips 66 as part of the separation of our Downstream businesses formally registered Phillips 66 as a party to the supply agreement, thereby triggering a guarantee we provided at the time of separation. Our maximum potential liability for future payments under this guarantee, which would become payable if Phillips 66 does not perform its contractual obligations under the supply agreement, is approximately $1.5 billion. At June 30, 2016, the carrying value of this guarantee is approximately $98 million and the remaining term is eight years. Because Phillips 66 has indemnified us for losses incurred under this guarantee, we have recorded an indemnification asset from Phillips 66 of

 

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approximately $98 million. The recorded indemnification asset amount represents the estimated fair value of the guarantee; however, if we are required to perform under the guarantee, we would expect to recover from Phillips 66 any amounts in excess of that value, provided Phillips 66 is a going concern.

Note 12—Contingencies and Commitments

A number of lawsuits involving a variety of claims arising in the ordinary course of business have been filed against ConocoPhillips. We also may be required to remove or mitigate the effects on the environment of the placement, storage, disposal or release of certain chemical, mineral and petroleum substances at various active and inactive sites. We regularly assess the need for accounting recognition or disclosure of these contingencies. In the case of all known contingencies (other than those related to income taxes), we accrue a liability when the loss is probable and the amount is reasonably estimable. If a range of amounts can be reasonably estimated but no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. We do not reduce these liabilities for potential insurance or third-party recoveries. If applicable, we accrue receivables for probable insurance or other third-party recoveries. With respect to income-tax-related contingencies, we use a cumulative probability-weighted loss accrual in cases where sustaining a tax position is less than certain.

Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures. Estimates particularly sensitive to future changes include contingent liabilities recorded for environmental remediation, tax and legal matters. Estimated future environmental remediation costs are subject to change due to factors such as the uncertain magnitude of cleanup costs, the unknown time and extent of such remedial actions that may be required, and the determination of our liability in proportion to that of other responsible parties. Estimated future costs related to tax and legal matters are subject to change as events evolve and as additional information becomes available during the administrative and litigation processes.

Environmental

We are subject to international, federal, state and local environmental laws and regulations. When we prepare our consolidated financial statements, we record accruals for environmental liabilities based on management’s best estimates, using all information that is available at the time. We measure estimates and base liabilities on currently available facts, existing technology, and presently enacted laws and regulations, taking into account stakeholder and business considerations. When measuring environmental liabilities, we also consider our prior experience in remediation of contaminated sites, other companies’ cleanup experience, and data released by the U.S. Environmental Protection Agency (EPA) or other organizations. We consider unasserted claims in our determination of environmental liabilities, and we accrue them in the period they are both probable and reasonably estimable.

Although liability of those potentially responsible for environmental remediation costs is generally joint and several for federal sites and frequently so for other sites, we are usually only one of many companies cited at a particular site. Due to the joint and several liabilities, we could be responsible for all cleanup costs related to any site at which we have been designated as a potentially responsible party. We have been successful to date in sharing cleanup costs with other financially sound companies. Many of the sites at which we are potentially responsible are still under investigation by the EPA or the agency concerned. Prior to actual cleanup, those potentially responsible normally assess the site conditions, apportion responsibility and determine the appropriate remediation. In some instances, we may have no liability or may attain a settlement of liability. Where it appears that other potentially responsible parties may be financially unable to bear their proportional share, we consider this inability in estimating our potential liability, and we adjust our accruals accordingly. As a result of various acquisitions in the past, we assumed certain environmental obligations. Some of these environmental obligations are mitigated by indemnifications made by others for our benefit and some of the indemnifications are subject to dollar limits and time limits.

 

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We are currently participating in environmental assessments and cleanups at numerous federal Superfund and comparable state and international sites. After an assessment of environmental exposures for cleanup and other costs, we make accruals on an undiscounted basis (except those acquired in a purchase business combination, which we record on a discounted basis) for planned investigation and remediation activities for sites where it is probable future costs will be incurred and these costs can be reasonably estimated. At June 30, 2016, our balance sheet included a total environmental accrual of $262 million, compared with $258 million at December 31, 2015, for remediation activities in the United States and Canada. We expect to incur a substantial amount of these expenditures within the next 30 years. In the future, we may be involved in additional environmental assessments, cleanups and proceedings.

Legal Proceedings

We are subject to various lawsuits and claims including but not limited to matters involving oil and gas royalty and severance tax payments, gas measurement and valuation methods, contract disputes, environmental damages, personal injury, and property damage. Our primary exposures for such matters relate to alleged royalty and tax underpayments on certain federal, state and privately owned properties and claims of alleged environmental contamination from historic operations. We will continue to defend ourselves vigorously in these matters.

Our legal organization applies its knowledge, experience and professional judgment to the specific characteristics of our cases, employing a litigation management process to manage and monitor the legal proceedings against us. Our process facilitates the early evaluation and quantification of potential exposures in individual cases. This process also enables us to track those cases that have been scheduled for trial and/or mediation. Based on professional judgment and experience in using these litigation management tools and available information about current developments in all our cases, our legal organization regularly assesses the adequacy of current accruals and determines if adjustment of existing accruals, or establishment of new accruals, is required.

Other Contingencies

We have contingent liabilities resulting from throughput agreements with pipeline and processing companies not associated with financing arrangements. Under these agreements, we may be required to provide any such company with additional funds through advances and penalties for fees related to throughput capacity not utilized. In addition, at June 30, 2016, we had performance obligations secured by letters of credit of $290 million (issued as direct bank letters of credit) related to various purchase commitments for materials, supplies, commercial activities and services incident to the ordinary conduct of business.

In 2007, we announced we had been unable to reach agreement with respect to our migration to an empresa mixta structure mandated by the Venezuelan government’s Nationalization Decree. As a result, Venezuela’s national oil company, Petróleos de Venezuela S.A. (PDVSA), or its affiliates, directly assumed control over ConocoPhillips’ interests in the Petrozuata and Hamaca heavy oil ventures and the offshore Corocoro development project. In response to this expropriation, we filed a request for international arbitration on November 2, 2007, with the World Bank’s International Centre for Settlement of Investment Disputes (ICSID). An arbitration hearing was held before an ICSID tribunal during the summer of 2010. On September 3, 2013, an ICSID arbitration tribunal held that Venezuela unlawfully expropriated ConocoPhillips’ significant oil investments in June 2007. A separate arbitration phase is currently proceeding to determine the damages owed to ConocoPhillips for Venezuela’s actions. On October 10, 2014, we filed a separate arbitration under the rules of the International Chamber of Commerce against PDVSA for contractual compensation related to the Petrozuata and Hamaca heavy crude oil projects.

In 2008, Burlington Resources, Inc., a wholly owned subsidiary of ConocoPhillips, initiated arbitration before ICSID against The Republic of Ecuador, as a result of the newly enacted Windfall Profits Tax Law and government-mandated renegotiation of our production sharing contracts. Despite a restraining order issued by the ICSID tribunal, Ecuador confiscated the crude oil production of Burlington and its co-venturer and sold the seized crude oil. In 2009, Ecuador took over operations in Blocks 7 and 21, fully expropriating our assets. In June 2010, the ICSID tribunal concluded it has jurisdiction to hear the expropriation claim. On April 24, 2012, Ecuador filed supplemental counterclaims asserting environmental damages, which we believe are not

 

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material. The ICSID tribunal issued a decision on liability on December 14, 2012, in favor of Burlington, finding that Ecuador’s seizure of Blocks 7 and 21 was an unlawful expropriation in violation of the Ecuador-U.S. Bilateral Investment Treaty. An additional arbitration phase to determine the damages owed to ConocoPhillips for Ecuador’s actions and to address Ecuador’s counterclaims is complete. We are awaiting the tribunal’s award.

ConocoPhillips served a Notice of Arbitration on the Timor-Leste Minister of Finance in October 2012 for outstanding disputes related to a series of tax assessments. The arbitration hearing was conducted in Singapore in June 2014 under the United Nations Commission on International Trade Laws (UNCITRAL) arbitration rules, pursuant to the terms of the Tax Stability Agreement with the Timor-Leste government. In January 2016, we settled three of the four Timor-Leste tax disputes. In March 2016, we received a decision from the arbitration tribunal on the fourth Timor-Leste tax dispute item and have reached a settlement in principle with the Timor-Leste government on this dispute.

Note 13—Derivative and Financial Instruments

Derivative Instruments

We use futures, forwards, swaps and options in various markets to meet our customer needs and capture market opportunities. Our commodity business primarily consists of natural gas, crude oil, bitumen, LNG and natural gas liquids.

Our derivative instruments are held at fair value on our consolidated balance sheet. Where these balances have the right of setoff, they are presented on a net basis. Related cash flows are recorded as operating activities on our consolidated statement of cash flows. On our consolidated income statement, realized and unrealized gains and losses are recognized either on a gross basis if directly related to our physical business or a net basis if held for trading. Gains and losses related to contracts that meet and are designated with the normal purchase normal sale exception are recognized upon settlement. We generally apply this exception to eligible crude contracts. We do not use hedge accounting for our commodity derivatives.

The following table presents the gross fair values of our commodity derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet:

 

                             
     Millions of Dollars  
     June 30
2016
     December 31
2015
 
  

 

 

 

Assets

     

Prepaid expenses and other current assets

   $ 333         768   

Other assets

     40         60   

Liabilities

     

Other accruals

     359         754   

Other liabilities and deferred credits

     33         46   

 

 

 

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The gains (losses) from commodity derivatives incurred, and the line items where they appear on our consolidated income statement were:

 

                                                           
     Millions of Dollars  
     Three Months Ended
June 30
    Six Months Ended
June 30
 
     2016     2015     2016     2015  
  

 

 

   

 

 

 

Sales and other operating revenues

   $ (163     44        (166     28   

Other income

     (3     2        (2     1   

Purchased commodities

     130        (47     129        (3

 

 

The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts:

 

                             
     Open Position
Long/(Short)
 
     June 30
2016
    December 31
2015
 
  

 

 

 

Commodity

    

Natural gas and power (billions of cubic feet equivalent)

    

Fixed price

     (11     (14

Basis

     27        (17

 

 

Foreign Currency Exchange Derivatives

We have foreign currency exchange rate risk resulting from international operations. Our foreign currency exchange derivative activity primarily relates to managing our cash-related and foreign currency exchange rate exposures, such as firm commitments for capital programs or local currency tax payments, dividends, and cash returns from net investments in foreign affiliates. We do not elect hedge accounting on our foreign currency exchange derivatives.

The following table presents the gross fair values of our foreign currency exchange derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet:

 

                             
     Millions of Dollars  
     June 30
2016
     December 31
2015
 
  

 

 

 

Assets

     

Prepaid expenses and other current assets

   $         47   

Liabilities

     

Other accruals

     104         8   

 

 

The (gains) losses from foreign currency exchange derivatives incurred, and the line item where they appear on our consolidated income statement were:

 

                                                           
     Millions of Dollars  
     Three Months Ended
June 30
    Six Months Ended
June 30
 
     2016      2015     2016      2015  
  

 

 

   

 

 

 

Foreign currency transaction (gains) losses

   $ 86         (37     183         (13

 

 

 

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We had the following net notional position of outstanding foreign currency exchange derivatives:

 

                                            
     In Millions
Notional Currency
 
    

June 30

2016

     December 31
2015
 
  

 

 

Sell U.S. dollar, buy other currencies*

   USD      2         347   

Buy U.S. dollar, sell other currencies**

   USD              20   

Buy British pound, sell other currencies***

   GBP      1,076         567   

 

 

    *Primarily Canadian dollar, Norwegian krone and British pound.

  **Primarily Canadian dollar and Norwegian krone.

***Primarily Canadian dollar and euro.

Financial Instruments

We have certain financial instruments on our consolidated balance sheet related to interest-bearing time deposits and commercial paper. These held-to-maturity financial instruments are included in “Cash and cash equivalents” on our consolidated balance sheet if the maturities at the time we made the investments were 90 days or less; otherwise, these investments are included in “Short-term investments” on our consolidated balance sheet.

 

                                                           
     Millions of Dollars  
     Carrying Amount  
     Cash and Cash Equivalents      Short-Term Investments  
    

June 30

2016

    

December 31

2015

    

June 30

2016

    

December 31

2015

 

 

 

Cash

   $ 837         528                   

Time deposits

           

Remaining maturities from 1 to 90 days

     2,026         1,840         682           

Remaining maturities from 91 to 180 days

                     607           

 

 
   $ 2,863         2,368         1,289           

 

 

Credit Risk

Financial instruments potentially exposed to concentrations of credit risk consist primarily of cash equivalents, short-term investments, over-the-counter (OTC) derivative contracts and trade receivables. Our cash equivalents and short-term investments are placed in high-quality commercial paper, money market funds, government debt securities and time deposits with major international banks and financial institutions.

The credit risk from our OTC derivative contracts, such as forwards and swaps, derives from the counterparty to the transaction. Individual counterparty exposure is managed within predetermined credit limits and includes the use of cash-call margins when appropriate, thereby reducing the risk of significant nonperformance. We also use futures, swaps and option contracts that have a negligible credit risk because these trades are cleared with an exchange clearinghouse and subject to mandatory margin requirements until settled; however, we are exposed to the credit risk of those exchange brokers for receivables arising from daily margin cash calls, as well as for cash deposited to meet initial margin requirements.

Our trade receivables result primarily from our petroleum operations and reflect a broad national and international customer base, which limits our exposure to concentrations of credit risk. The majority of these receivables have payment terms of 30 days or less, and we continually monitor this exposure and the creditworthiness of the counterparties. We do not generally require collateral to limit the exposure to loss;

 

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however, we will sometimes use letters of credit, prepayments and master netting arrangements to mitigate credit risk with counterparties that both buy from and sell to us, as these agreements permit the amounts owed by us or owed to others to be offset against amounts due to us.

Certain of our derivative instruments contain provisions that require us to post collateral if the derivative exposure exceeds a threshold amount. We have contracts with fixed threshold amounts and other contracts with variable threshold amounts that are contingent on our credit rating. The variable threshold amounts typically decline for lower credit ratings, while both the variable and fixed threshold amounts typically revert to zero if we fall below investment grade. Cash is the primary collateral in all contracts; however, many also permit us to post letters of credit as collateral, such as transactions administered through the New York Mercantile Exchange.

The aggregate fair value of all derivative instruments with such credit-risk-related contingent features that were in a liability position on June 30, 2016 and December 31, 2015, was $79 million and $158 million, respectively. For these instruments, $1 million of collateral was posted as of June 30, 2016, and $2 million of collateral was posted as of December 31, 2015. If our credit rating had been downgraded below investment grade on June 30, 2016, we would be required to post $78 million of additional collateral, either with cash or letters of credit.

Note 14—Fair Value Measurement

We carry a portion of our assets and liabilities at fair value that are measured at a reporting date using an exit price (i.e., the price that would be received to sell an asset or paid to transfer a liability) and disclosed according to the quality of valuation inputs under the following hierarchy:

 

   

Level 1: Quoted prices (unadjusted) in an active market for identical assets or liabilities.

   

Level 2: Inputs other than quoted prices that are directly or indirectly observable.

   

Level 3: Unobservable inputs that are significant to the fair value of assets or liabilities.

The classification of an asset or liability is based on the lowest level of input significant to its fair value. Those that are initially classified as Level 3 are subsequently reported as Level 2 when the fair value derived from unobservable inputs is inconsequential to the overall fair value, or if corroborated market data becomes available. Assets and liabilities that are initially reported as Level 2 are subsequently reported as Level 3 if corroborated market data is no longer available. Transfers occur at the end of the reporting period. There were no material transfers in or out of Level 1 during 2016 or 2015.

Recurring Fair Value Measurement

Financial assets and liabilities reported at fair value on a recurring basis primarily include commodity derivatives. Level 1 derivative assets and liabilities primarily represent exchange-traded futures and options that are valued using unadjusted prices available from the underlying exchange. Level 2 derivative assets and liabilities primarily represent OTC swaps, options and forward purchase and sale contracts that are valued using adjusted exchange prices, prices provided by brokers or pricing service companies that are all corroborated by market data. Level 3 derivative assets and liabilities consist of OTC swaps, options and forward purchase and sale contracts where a significant portion of fair value is calculated from underlying market data that is not readily available. The derived value uses industry standard methodologies that may consider the historical relationships among various commodities, modeled market prices, time value, volatility factors and other relevant economic measures. The use of these inputs results in management’s best estimate of fair value. Level 3 activity was not material for all periods presented.

 

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The following table summarizes the fair value hierarchy for gross financial assets and liabilities (i.e., unadjusted where the right of setoff exists for commodity derivatives accounted for at fair value on a recurring basis):

 

                                                                                                                       
     Millions of Dollars  
     June 30, 2016      December 31, 2015  
     Level 1      Level 2      Level 3      Total      Level 1      Level 2      Level 3      Total  
  

 

 

    

 

 

 

Assets

                       

Commodity derivatives

   $ 220         129         24         373         516         242         70         828   

 

 

Total assets

   $ 220         129         24         373         516         242         70         828   

 

 

Liabilities

                       

Commodity derivatives

   $ 234         141         17         392         515         273         12         800   

 

 

Total liabilities

   $ 234         141         17         392         515         273         12         800   

 

 

The following table summarizes those commodity derivative balances subject to the right of setoff as presented on our consolidated balance sheet. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements when a legal right of setoff exists.

 

                                                                                         
     Millions of Dollars  
     Gross
Amounts
Recognized
     Gross
Amounts
Offset
     Net
Amounts
Presented
     Cash
Collateral
    

Gross Amounts

without
Right of Setoff

     Net
Amounts
 
  

 

 

 

June 30, 2016

                 

Assets

   $ 373         275         98                 8         90   

Liabilities

     392         275         117         10         14         93   

 

 

December 31, 2015

                 

Assets

   $ 828         600         228                 8         220   

Liabilities

     800         600         200         1         11         188   

 

 

At June 30, 2016 and December 31, 2015, we did not present any amounts gross on our consolidated balance sheet where we had the right of setoff.

Non-Recurring Fair Value Measurement

The following table summarizes the fair value hierarchy by major category and date of remeasurement for assets accounted for at fair value on a non-recurring basis during the year:

 

                                            
     Millions of Dollars  
            Fair Value
Measurements Using
 
     Fair Value      Level 3
Inputs
     Before-
Tax Loss
 
  

 

 

    

 

 

    

 

 

 

June 30, 2016

        

Net PP&E (held for use)

   $ 23         23         53   

 

 

March 31, 2016

        

Net PP&E (held for use)

   $ 217         217         129   

 

 

 

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Net PP&E held for use is comprised of various producing properties impaired to their individual fair values less costs to sell. The fair values were determined by internal discounted cash flow models using estimates of future production, prices from futures exchanges and pricing service companies, costs, and a discount factor believed to be consistent with those used by principal market participants.

Reported Fair Values of Financial Instruments

We used the following methods and assumptions to estimate the fair value of financial instruments:

 

   

Cash and cash equivalents and short-term investments: The carrying amount reported on the balance sheet approximates fair value.

   

Accounts and notes receivable (including long-term and related parties): The carrying amount reported on the balance sheet approximates fair value. The valuation technique and methods used to estimate the fair value of the current portion of fixed-rate related party loans is consistent with Loans and advances—related parties.

   

Loans and advances—related parties: The carrying amount of floating-rate loans approximates fair value. The fair value of fixed-rate loan activity is measured using market observable data and is categorized as Level 2 in the fair value hierarchy. See Note 6—Investments, Loans and Long-Term Receivables, for additional information.

   

Accounts payable (including related parties) and floating-rate debt: The carrying amount of accounts payable and floating-rate debt reported on the balance sheet approximates fair value.

   

Fixed-rate debt: The estimated fair value of fixed-rate debt is measured using prices available from a pricing service that is corroborated by market data; therefore, these liabilities are categorized as Level 2 in the fair value hierarchy.

The following table summarizes the net fair value of financial instruments (i.e., adjusted where the right of setoff exists for commodity derivatives):

 

                                                           
     Millions of Dollars  
     Carrying Amount      Fair Value  
     June 30
2016
     December 31
2015
     June 30
2016
     December 31
2015
 
  

 

 

    

 

 

 

Financial assets

           

Commodity derivatives

   $ 98         228         98         228   

Total loans and advances—related parties

     755         808         755         808   

Financial liabilities

           

Total debt, excluding capital leases

     27,824         24,062         31,001         24,785   

Commodity derivatives

     107         199         107         199   

 

 

 

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Note 15—Accumulated Other Comprehensive Income (Loss)

Accumulated other comprehensive loss in the equity section of our consolidated balance sheet included:

 

                                            
     Millions of Dollars  
     Defined
Benefit Plans
    Foreign
Currency
Translation
    Accumulated
Other
Comprehensive
Income (Loss)
 
  

 

 

 

December 31, 2015

   $ (443     (5,804     (6,247

Other comprehensive income (loss)

     (83     959        876   

 

 

June 30, 2016

   $ (526     (4,845     (5,371

 

 

Foreign Currency Translation increased due to the weakening of the U.S. dollar relative to the Canadian dollar, Australian dollar and Norwegian krone.

The following table summarizes reclassifications out of accumulated other comprehensive loss:

 

                                                           
     Millions of Dollars  
     Three Months Ended
June 30
     Six Months Ended
June 30
 
     2016      2015      2016      2015  
  

 

 

    

 

 

 

Defined benefit plans

   $ 42         64         105         96   

 

 
Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of:    $ 23         35         59         52   

See Note 17Employee Benefit Plans, for additional information.

There were no items within accumulated other comprehensive loss related to noncontrolling interests.

Note 16—Cash Flow Information

 

                             
     Millions of Dollars  
     Six Months Ended
June 30
 
     2016     2015  
  

 

 

 

Cash Payments (Receipts)

    

Interest

   $ 526        399   

Income taxes*

     (366     172   

 

 

Net Sales (Purchases) of Short-Term Investments

    

Short-term investments purchased

   $ (1,599       

Short-term investments sold

     307          

 

 
   $ (1,292       

 

 

*Net of $569 million and $556 million in 2016 and 2015, respectively, related to refunds received from the Internal Revenue Service.

In May 2015, we liquidated certain deferred compensation investments for proceeds of $267 million, which is included in the “Other” line within “Cash Flows From Investing Activities” on our consolidated statement of cash flows.

 

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Note 17—Employee Benefit Plans

Pension and Postretirement Plans

 

                                                                                         
     Millions of Dollars  
     Pension Benefits     Other Benefits  
     2016     2015     2016     2015  
  

 

 

   

 

 

   

 

 

 
     U.S.     Int’l.     U.S.     Int’l.              
  

 

 

   

 

 

   

 

 

   

 

 

     

Components of Net Periodic Benefit Cost

            

Three Months Ended June 30

            

Service cost

   $ 28        20        36        31                 

Interest cost

     32        32        39        34        4        7   

Expected return on plan assets

     (35     (41     (53     (43              

Amortization of prior service cost (credit)

     1        (2     1        (2     (8     (2

Recognized net actuarial loss (gain)

     23        7        29        21        (1       

Settlements

     45               52                        

 

 

Net periodic benefit cost

   $ 94        16        104        41        (5     5   

 

 

Six Months Ended June 30

            

Service cost

   $ 55        40        72        63        1        1   

Interest cost

     72        63        79        68        7        14   

Expected return on plan assets

     (78     (82     (107     (87              

Amortization of prior service cost (credit)

     2        (3     3        (4     (17     (3

Recognized net actuarial loss (gain)

     42        14        57        42        (1     1   

Settlements

     127               52                        

 

 

Net periodic benefit cost

   $ 220        32        156        82        (10     13   

 

 

During the first six months of 2016, we contributed $111 million to our domestic benefit plans and $61 million to our international benefit plans. In 2016, we expect to contribute approximately $260 million to our domestic qualified and nonqualified pension and postretirement benefit plans and $130 million to our international qualified and nonqualified pension and postretirement benefit plans.

In conjunction with the recognition of pension settlement expense, the fair market values of pension plan assets were updated, and the pension benefit obligations of the U.S. qualified pension plan and a U.S. nonqualified supplemental retirement plan were remeasured. At the measurement dates, the net pension liability increased by $69 million and $300 million for the three- and six-month periods ended June 30, 2016, respectively. This is primarily a result of a decrease in the discount rate from 4.5 percent at December 31, 2015, to 3.6 percent for the U.S. qualified pension plan and to 3.15 percent for a U.S. nonqualified supplemental retirement plan at June 30, 2016, resulting in a corresponding decrease to other comprehensive income (loss).

Severance Accrual

The following table summarizes our severance accrual activity for the six-month period ended June 30, 2016:

 

              
     Millions of Dollars  

Balance at December 31, 2015

   $ 156   

Accruals

     7   

Accrual reversals

     (1

Benefit payments

     (115

Foreign currency translation adjustments

     2   

 

 

Balance at June 30, 2016

   $ 49   

 

 

Of the remaining balance at June 30, 2016, $16 million is classified as short-term.

 

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Note 18—Related Party Transactions

Our related parties primarily include equity method investments and certain trusts for the benefit of employees.

Significant transactions with our equity affiliates were:

 

                                                           
     Millions of Dollars  
     Three Months Ended
June 30
    Six Months Ended
June 30
 
     2016     2015     2016     2015  
  

 

 

   

 

 

 

Operating revenues and other income

   $ 28        27        55        52   

Purchases

     25        25        49        47   

Operating expenses and selling, general and administrative expenses

     12        17        28        35   

Net interest (income) expense*

     (3     (2     (6     (4

 

 

*We paid interest to, or received interest from, various affiliates. See Note 6—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.

Note 19—Segment Disclosures and Related Information

We explore for, produce, transport and market crude oil, bitumen, natural gas, LNG and natural gas liquids on a worldwide basis. We manage our operations through six operating segments, which are primarily defined by geographic region: Alaska, Lower 48, Canada, Europe and North Africa, Asia Pacific and Middle East, and Other International.

Effective November 1, 2015, the Other International and historically presented Europe segments were restructured to align with changes to our internal organization structure. The Libya business was moved from the Other International segment to the historically presented Europe segment, which is now renamed Europe and North Africa. Accordingly, results of operations for the Other International and Europe and North Africa segments have been revised for all prior periods presented. There was no impact on our consolidated financial statements, and the impact on our segment presentation is immaterial.

Corporate and Other represents costs not directly associated with an operating segment, such as most interest expense, corporate overhead and certain technology activities, including licensing revenues. Corporate assets include all cash and cash equivalents and short-term investments.

We evaluate performance and allocate resources based on net income (loss) attributable to ConocoPhillips. Intersegment sales are at prices that approximate market.

 

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Table of Contents

Analysis of Results by Operating Segment

 

                                                           
     Millions of Dollars  
     Three Months Ended
June 30
    Six Months Ended
June 30
 
     2016     2015     2016     2015  
  

 

 

   

 

 

 

Sales and Other Operating Revenues

        

Alaska

   $ 936        1,338        1,714        2,388   

 

 

Lower 48

     2,395        3,176        4,540        6,315   

Intersegment eliminations

     (5     (13     (12     (35

 

 

Lower 48

     2,390        3,163        4,528        6,280   

 

 

Canada

     391        653        816        1,356   

Intersegment eliminations

     (30     (79     (65     (189

 

 

Canada

     361        574        751        1,167   

 

 

Europe and North Africa

     736        1,775        1,659        3,324   

Intersegment eliminations

            (1            (1

 

 

Europe and North Africa

     736        1,774        1,659        3,323   

 

 

Asia Pacific and Middle East

     897        1,286        1,734        2,674   

Corporate and Other

     28        158        83        177   

 

 

Consolidated sales and other operating revenues

   $ 5,348        8,293        10,469        16,009   

 

 

Net Income (Loss) Attributable to ConocoPhillips

        

Alaska

   $ 147        195        145        340   

Lower 48

     (771     (293     (1,591     (698

Canada

     (175     (166     (469     (324

Europe and North Africa

     20        36        (31     672   

Asia Pacific and Middle East

     72        328        67        723   

Other International

     (29     (147     (53     (239

Corporate and Other

     (335     (132     (608     (381

 

 

Consolidated net income (loss) attributable to ConocoPhillips

   $ (1,071     (179     (2,540     93   

 

 

 

                             
     Millions of Dollars  
    

June 30

2016

     December 31
2015
 
  

 

 

 

Total Assets

     

Alaska

   $ 12,612         12,555   

Lower 48

     24,271         26,932   

Canada

     18,400         17,221   

Europe and North Africa

     13,060         13,703   

Asia Pacific and Middle East

     21,769         22,318   

Other International

     375         282   

Corporate and Other

     5,567         4,473   

 

 

Consolidated total assets

   $ 96,054         97,484   

 

 

Note 20—Income Taxes

Our effective tax rates for the second quarter and first six months of 2016 were positive 36 percent and 35 percent, respectively, compared with negative 80 percent and positive 127 percent for the same periods of 2015. The increase in the effective tax rate for the second quarter of 2016 was primarily due to the effect of the recognition of state deferred tax assets and the absence of the effect of the 2015 Canadian tax law change generating a tax expense, both discussed below, partially offset by a shift in the mix of income between high and low tax jurisdictions. The decrease in the effective tax rate for the first six months of 2016 was primarily

 

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due to the absence of the effect of the 2015 U.K. tax law change, discussed below, partially offset by the recognition of state deferred tax assets and the second-quarter 2015 Canadian tax law change.

During the second quarter of 2016, previously unrecognized state deferred tax assets were recognized. As a result, a $68 million tax benefit is reflected in the “Income tax provision (benefit)” line on our consolidated income statement.

In the United Kingdom, legislation was enacted on March 26, 2015, to decrease the overall U.K. upstream corporation tax rate from 62 percent to 50 percent effective January 1, 2015. As a result, a $555 million net tax benefit for revaluing the U.K. deferred tax liability is reflected in the “Income tax provision (benefit)” line on our consolidated income statement.

In Canada, legislation was enacted on June 29, 2015, to increase the overall Canadian corporation tax rate from 25 percent to 27 percent effective July 1, 2015. As a result, a $129 million net tax expense for revaluing the Canadian deferred tax liability is reflected in the “Income tax provision (benefit)” line on our consolidated income statement.

Note 21—New Accounting Standards

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers” (ASU No. 2014-09), which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers. This ASU supersedes the revenue recognition requirements in FASB ASC Topic 605, “Revenue Recognition,” and most industry-specific guidance. This ASU sets forth a five-step model for determining when and how revenue is recognized. Under the model, an entity will be required to recognize revenue to depict the transfer of goods or services to a customer at an amount reflecting the consideration it expects to receive in exchange for those goods or services. Additional disclosures will be required to describe the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts.

In August 2015, the FASB issued ASU No. 2015-14, “Deferral of the Effective Date,” which defers the effective date of ASU No. 2014-09. The ASU is now effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted for interim and annual periods beginning after December 15, 2016. Entities may choose to adopt the standard using either a full retrospective approach or a modified retrospective approach.

ASU No. 2014-09 was amended in March 2016 by the provisions of ASU No. 2016-08, “Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” in April 2016 by the provisions of ASU No. 2016-10, “Identifying Performance Obligations and Licensing,” and in May 2016 by the provisions of ASU No. 2016-12, “Narrow-Scope Improvements and Practical Expedients.” We are currently evaluating the impact of the adoption of ASU No. 2014-09, as amended, and continue to monitor proposals issued by the FASB to clarify the ASU.

In February 2016, the FASB issued ASU No. 2016-02, “Leases” (ASU No. 2016-02), which establishes comprehensive accounting and financial reporting requirements for leasing arrangements. This ASU supersedes the existing requirements in FASB ASC Topic 840, “Leases,” and requires lessees to recognize substantially all lease assets and lease liabilities on the balance sheet. The provisions of ASU No. 2016-02 also modify the definition of a lease and outline requirements for recognition, measurement, presentation, and disclosure of leasing arrangements by both lessees and lessors. The ASU is effective for interim and annual periods beginning after December 15, 2018, and early adoption of the standard is permitted. Entities are required to adopt the ASU using a modified retrospective approach, subject to certain optional practical expedients, and apply the provisions of ASU No. 2016-02 to leasing arrangements existing at or entered into after the earliest comparative period presented in the financial statements. We are currently evaluating the impact of the adoption of this ASU.

 

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Table of Contents

In June 2016, the FASB issued ASU No. 2016-13, “Measurement of Credit Losses on Financial Instruments” (ASU No. 2016-13), which sets forth the current expected credit loss model, a new forward-looking impairment model for certain financial instruments based on expected losses rather than incurred losses. The ASU is effective for interim and annual periods beginning after December 15, 2019, and early adoption of the standard is permitted. Entities are required to adopt ASU No. 2016-13 using a modified retrospective approach, subject to certain limited exceptions. We are currently evaluating the impact of the adoption of this ASU.

Note 22—Subsequent Events

In July 2016, we entered into an agreement to terminate our final Gulf of Mexico deepwater drillship contract. The drillship, used to drill our operated deepwater well inventory in the Gulf of Mexico through April 2016, was contracted on a shared, three-year term. We expect to record before-tax rig cancellation charges and third party costs of approximately $140 million in our third quarter 2016 earnings.

On July 1, 2016, APLNG changed its tax functional currency from Australian dollar to U.S. dollar and translated all APLNG assets and liabilities into U.S. dollar, utilizing the exchange rate as of that date. As a result of this change, we will record a reduction to our investment in APLNG for the deferred tax effect of approximately $200 million, to be recorded through equity earnings in the third quarter of 2016.

In July 2016, we announced our plan to sell our 35 percent interest in three exploration blocks offshore Senegal for $350 million plus net customary adjustments of approximately $80 million. The three blocks had a net book value of approximately $273 million as of June 30, 2016. The transactions are expected to close by year-end 2016, subject to governmental approvals and co-venturer preemption rights. Senegal results of operations are reported within our Other International segment.

In July 2016, we announced targeted workforce reductions in certain areas of our business. Approximately 6 percent of our global workforce will be affected. As the analysis is ongoing, it is not reasonably practicable to quantify the financial impact, but the impact could be material to our results of operations in the third quarter of 2016.

 

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Table of Contents

Supplementary Information—Condensed Consolidating Financial Information

We have various cross guarantees among ConocoPhillips, ConocoPhillips Company and ConocoPhillips Canada Funding Company I, with respect to publicly held debt securities. ConocoPhillips Company is 100 percent owned by ConocoPhillips. ConocoPhillips Canada Funding Company I is an indirect, 100 percent owned subsidiary of ConocoPhillips Company. ConocoPhillips and ConocoPhillips Company have fully and unconditionally guaranteed the payment obligations of ConocoPhillips Canada Funding Company I, with respect to its publicly held debt securities. Similarly, ConocoPhillips has fully and unconditionally guaranteed the payment obligations of ConocoPhillips Company with respect to its publicly held debt securities. In addition, ConocoPhillips Company has fully and unconditionally guaranteed the payment obligations of ConocoPhillips with respect to its publicly held debt securities. All guarantees are joint and several. The following condensed consolidating financial information presents the results of operations, financial position and cash flows for:

 

   

ConocoPhillips, ConocoPhillips Company and ConocoPhillips Canada Funding Company I (in each case, reflecting investments in subsidiaries utilizing the equity method of accounting).

   

All other nonguarantor subsidiaries of ConocoPhillips.

   

The consolidating adjustments necessary to present ConocoPhillips’ results on a consolidated basis.

In February 2016, ConocoPhillips received a $2.3 billion return of capital from ConocoPhillips Company to settle certain accumulated intercompany balances. The transaction had no impact on our consolidated financial statements.

This condensed consolidating financial information should be read in conjunction with the accompanying consolidated financial statements and notes.

 

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Table of Contents
                                                                                         
     Millions of Dollars  
     Three Months Ended June 30, 2016  
Income Statement    ConocoPhillips     ConocoPhillips
Company
    ConocoPhillips
Canada
Funding
Company I
    All Other
Subsidiaries
    Consolidating
Adjustments
    Total
Consolidated
 

Revenues and Other Income

            

Sales and other operating revenues

   $        2,284               3,064               5,348   

Equity in earnings (losses) of affiliates

     (1,003     (21            145        959        80   

Gain on dispositions

            63               65               128   

Other income

            1               18               19   

Intercompany revenues

     26        68        60        928        (1,082       

 

 

Total Revenues and Other Income

     (977     2,395        60        4,220        (123     5,575   

 

 

Costs and Expenses

            

Purchased commodities

            1,998               682        (678     2,002   

Production and operating expenses

            488               1,191        (234     1,445   

Selling, general and administrative expenses

     2        136               29               167   

Exploration expenses

            551               59               610   

Depreciation, depletion and amortization

            306               2,023               2,329   

Impairments

            37               25               62   

Taxes other than income taxes

            39               158               197   

Accretion on discounted liabilities

            12               100               112   

Interest and debt expense

     126        164        57        135        (170     312   

Foreign currency transaction (gains) losses

     2               (79     60               (17

 

 

Total Costs and Expenses

     130        3,731        (22     4,462        (1,082     7,219   

 

 

Income (loss) before income taxes

     (1,107     (1,336     82        (242     959        (1,644

Income tax provision (benefit)

     (36     (333     19        (236            (586

 

 

Net income (loss)

     (1,071     (1,003     63        (6     959        (1,058

Less: net income attributable to noncontrolling interests

                          (13            (13

 

 

Net Income (Loss) Attributable to ConocoPhillips

   $ (1,071     (1,003     63        (19     959        (1,071

 

 

Comprehensive Income (Loss) Attributable to ConocoPhillips

   $ (1,296     (1,228     51        (215     1,392        (1,296

 

 
Income Statement    Three Months Ended June 30, 2015  

Revenues and Other Income

            

Sales and other operating revenues

   $        3,102               5,191               8,293   

Equity in earnings (losses) of affiliates

     (120     215               138        25        258   

Gain on dispositions

            2               50               52   

Other income

            10               47               57   

Intercompany revenues

     18        82        63        952        (1,115       

 

 

Total Revenues and Other Income

     (102     3,411        63        6,378        (1,090     8,660   

 

 

Costs and Expenses

            

Purchased commodities

            2,568               1,610        (948     3,230   

Production and operating expenses

            395               1,405        (2     1,798   

Selling, general and administrative expenses

     3        162               53               218   

Exploration expenses

            143               406               549   

Depreciation, depletion and amortization

            301               2,028               2,329   

Impairments

                          78               78   

Taxes other than income taxes

            50               175               225   

Accretion on discounted liabilities

            15               107               122   

Interest and debt expense

     121        111        57        86        (165     210   

Foreign currency transaction (gains) losses

     (16     1        146        (139            (8

 

 

Total Costs and Expenses

     108        3,746        203        5,809        (1,115     8,751   

 

 

Income (loss) before income taxes

     (210     (335     (140     569        25        (91

Income tax provision (benefit)

     (31     (215     (20     339               73   

 

 

Net income (loss)

     (179     (120     (120     230        25        (164

Less: net income attributable to noncontrolling interests

                          (15            (15

 

 

Net Income (Loss) Attributable to ConocoPhillips

   $ (179     (120     (120     215        25        (179

 

 

Comprehensive Income (Loss) Attributable to ConocoPhillips

   $ 769        828        (33     988        (1,783     769   

 

 

 

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Table of Contents
                                                                                         
     Millions of Dollars  
     Six Months Ended June 30, 2016  
Income Statement    ConocoPhillips     ConocoPhillips
Company
    ConocoPhillips
Canada
Funding
Company I
    All Other
Subsidiaries
    Consolidating
Adjustments
    Total
Consolidated
 

Revenues and Other Income

            

Sales and other operating revenues

   $        4,356               6,113               10,469   

Equity in earnings (losses) of affiliates

     (2,430     (771            (299     3,431        (69

Gain on dispositions

            85               66               151   

Other income (loss)

            (5            44               39   

Intercompany revenues

     44        149        116        1,453        (1,762       

 

 

Total Revenues and Other Income

     (2,386     3,814        116        7,377        1,669        10,590   

 

 

Costs and Expenses

            

Purchased commodities

            3,846               1,561        (1,180     4,227   

Production and operating expenses

            741               2,295        (237     2,799   

Selling, general and administrative expenses

     5        290               64        (6     353   

Exploration expenses

            982               133               1,115   

Depreciation, depletion and amortization

            563               4,013               4,576   

Impairments

            41               157               198   

Taxes other than income taxes

            96               281               377   

Accretion on discounted liabilities

            24               197               221   

Interest and debt expense

     250        298        112        272        (339     593   

Foreign currency transaction (gains) losses

     (42     2        233        (194            (1

 

 

Total Costs and Expenses

     213        6,883        345        8,779        (1,762     14,458   

 

 

Loss before income taxes

     (2,599     (3,069     (229     (1,402     3,431        (3,868

Income tax provision (benefit)

     (59     (639     1        (657            (1,354

 

 

Net loss

     (2,540     (2,430     (230     (745     3,431        (2,514

Less: net income attributable to noncontrolling interests

                          (26            (26

 

 

Net Loss Attributable to ConocoPhillips

   $ (2,540     (2,430     (230     (771     3,431        (2,540

 

 

Comprehensive Income (Loss) Attributable to ConocoPhillips

   $ (1,664     (1,554     4        230        1,320        (1,664

 

 
Income Statement    Six Months Ended June 30, 2015  

Revenues and Other Income

            

Sales and other operating revenues

   $        6,035               9,974               16,009   

Equity in earnings of affiliates

     261        1,028               716        (1,542     463   

Gain on dispositions

            33               71               104   

Other income

            17               69               86   

Intercompany revenues

     37        180        127        1,795        (2,139       

 

 

Total Revenues and Other Income

     298        7,293        127        12,625        (3,681     16,662   

 

 

Costs and Expenses

            

Purchased commodities

            5,128               3,104        (1,765     6,467   

Production and operating expenses

            795               2,839        (34     3,600   

Selling, general and administrative expenses

     6        282               98        (9     377   

Exploration expenses

            343               688               1,031   

Depreciation, depletion and amortization

            560               3,900               4,460   

Impairments

                          94               94   

Taxes other than income taxes

            119               330               449   

Accretion on discounted liabilities

            29               214               243   

Interest and debt expense

     242        212        114        175        (331     412   

Foreign currency transaction (gains) losses

     47               (232     161               (24

 

 

Total Costs and Expenses

     295        7,468        (118     11,603        (2,139     17,109   

 

 

Income (loss) before income taxes

     3        (175     245        1,022        (1,542     (447

Income tax benefit

     (90     (436     (9     (34            (569

 

 

Net income

     93        261        254        1,056        (1,542     122   

Less: net income attributable to noncontrolling interests

                          (29            (29

 

 

Net Income Attributable to ConocoPhillips

   $ 93        261        254        1,027        (1,542     93   

 

 

Comprehensive Income (Loss) Attributable to ConocoPhillips

   $ (1,646     (1,478     (3     (886     2,367        (1,646

 

 

 

27


Table of Contents
                                                                                         
     Millions of Dollars  
     June 30, 2016  
Balance Sheet    ConocoPhillips     ConocoPhillips
Company
    ConocoPhillips
Canada
Funding
Company I
    All Other
Subsidiaries
     Consolidating
Adjustments
    Total
Consolidated
 

Assets

             

Cash and cash equivalents

   $        265        10        2,588                2,863   

Short-term investments

                          1,289                1,289   

Accounts and notes receivable

     11        1,401        24        4,622         (2,742     3,316   

Inventories

            100               1,050                1,150   

Prepaid expenses and other current assets

     1        141        167        519         (187     641   

 

 

Total Current Assets

     12        1,907        201        10,068         (2,929     9,259   

Investments, loans and long-term receivables*

     40,356        61,672        3,501        27,849         (111,354     22,024   

Net properties, plants and equipment

            6,994               56,691                63,685   

Other assets

     8        1,835        229        1,298         (2,284     1,086   

 

 

Total Assets

   $ 40,376        72,408        3,931        95,906         (116,567     96,054   

 

 

Liabilities and Stockholders’ Equity

             

Accounts payable

   $        3,234        6        3,320         (2,742     3,818   

Short-term debt

     (10     (2     1,256        87                1,331   

Accrued income and other taxes

            51               503                554   

Employee benefit obligations

            370               168                538   

Other accruals

     170        262        59        802         (186     1,107   

 

 

Total Current Liabilities

     160        3,915        1,321        4,880         (2,928     7,348   

Long-term debt

     9,120        13,635        1,713        2,878                27,346   

Asset retirement obligations and accrued environmental costs

            1,127               8,693                9,820   

Deferred income taxes

                          11,360         (1,705     9,655   

Employee benefit obligations

            2,034               499                2,533   

Other liabilities and deferred credits*

     114        6,877        811        16,099         (22,380     1,521   

 

 

Total Liabilities

     9,394        27,588        3,845        44,409         (27,013     58,223   

Retained earnings (losses)

     26,725        14,937        (619     13,262         (21,057     33,248   

Other common stockholders’ equity

     4,257        29,883        705        37,948         (68,497     4,296   

Noncontrolling interests

                          287                287   

 

 

Total Liabilities and Stockholders’ Equity

   $ 40,376        72,408        3,931        95,906         (116,567     96,054   

 

 

*Includes intercompany loans.

             
Balance Sheet    December 31, 2015  

Assets

             

Cash and cash equivalents

   $        4        15        2,349                2,368   

Accounts and notes receivable

     21        2,905        21        7,228         (5,661     4,514   

Inventories

            142               982                1,124   

Prepaid expenses and other current assets

     2        206        252        589         (266     783   

 

 

Total Current Assets

     23        3,257        288        11,148         (5,927     8,789   

Investments, loans and long-term receivables*

     43,532        64,015        3,264        27,839         (117,464     21,186   

Net properties, plants and equipment

            8,110               58,336                66,446   

Other assets

     7        950        233        1,158         (1,285     1,063   

 

 

Total Assets

   $ 43,562        76,332        3,785        98,481         (124,676     97,484   

 

 

Liabilities and Stockholders’ Equity

             

Accounts payable

   $        5,684        13        4,897         (5,661     4,933   

Short-term debt

     (9     1        1,255        180                1,427   

Accrued income and other taxes

            62               437                499   

Employee benefit obligations

            629               258                887   

Other accruals

     170        465        52        1,087         (264     1,510   

 

 

Total Current Liabilities

     161        6,841        1,320        6,859         (5,925     9,256   

Long-term debt

     7,518        10,660        1,716        3,559                23,453   

Asset retirement obligations and accrued environmental costs

            1,107               8,473                9,580   

Deferred income taxes

                          11,814         (815     10,999   

Employee benefit obligations

            1,760               526                2,286   

Other liabilities and deferred credits*

     2,681        7,291        667        15,181         (23,992     1,828   

 

 

Total Liabilities

     10,360        27,659        3,703        46,412         (30,732     57,402   

Retained earnings (losses)

     29,892        17,366        (389     15,177         (25,632     36,414   

Other common stockholders’ equity

     3,310        31,307        471        36,572         (68,312     3,348   

Noncontrolling interests

                          320                320   

 

 

Total Liabilities and Stockholders’ Equity

   $ 43,562        76,332        3,785        98,481         (124,676     97,484   

 

 

*Includes intercompany loans.

             

 

28


Table of Contents
                                                                                         
     Millions of Dollars  
     Six Months Ended June 30, 2016  
Statement of Cash Flows    ConocoPhillips     ConocoPhillips
Company
    ConocoPhillips
Canada
Funding
Company I
    All Other
Subsidiaries
    Consolidating
Adjustments
    Total
Consolidated
 

Cash Flows From Operating Activities

            

Net Cash Provided by (Used in) Operating Activities

   $ (153     572        (5     2,229        (963     1,680   

 

 

Cash Flows From Investing Activities

            

Capital expenditures and investments

            (823            (2,532     401        (2,954

Working capital changes associated with investing activities

            (76            (287            (363

Proceeds from asset dispositions

     2,300        160               227        (2,324     363   

Purchases of short-term investments

                          (1,292            (1,292

Long-term advances/loans—related parties

            (803                   803          

Collection of advances/loans—related parties

                          1,626        (1,573     53   

Intercompany cash management

     (3,190     2,127               1,063                 

Other

            2               4               6   

 

 

Net Cash Provided by (Used in) Investing Activities

     (890     587               (1,191     (2,693     (4,187

 

 

Cash Flows From Financing Activities

            

Issuance of debt

     1,600        2,994               803        (803     4,594   

Repayment of debt

            (1,573            (827     1,573        (827

Issuance of company common stock

     70                             (115     (45

Dividends paid

     (626                   (1,078     1,078        (626

Other

     (1     (2,319            318        1,923        (79

 

 

Net Cash Provided by (Used in) Financing Activities

     1,043        (898            (784     3,656        3,017   

 

 

Effect of Exchange Rate Changes on Cash and Cash Equivalents

                          (15            (15

 

 

Net Change in Cash and Cash Equivalents

            261        (5     239               495   

Cash and cash equivalents at beginning of period

            4        15        2,349               2,368   

 

 

Cash and Cash Equivalents at End of Period

   $        265        10        2,588               2,863   

 

 
Statement of Cash Flows    Six Months Ended June 30, 2015  

Cash Flows From Operating Activities

            

Net Cash Provided by (Used in) Operating Activities

   $ (124     348        1        3,623        194        4,042   

 

 

Cash Flows From Investing Activities

            

Capital expenditures and investments

            (1,642            (4,773     676        (5,739

Working capital changes associated with investing activities

            (27            (651            (678

Proceeds from asset dispositions

     2,000        94               205        (2,005     294   

Long-term advances/loans—related parties

            (179            (551     730          

Collection of advances/loans—related parties

                          152        (100     52   

Intercompany cash management

     (231     (574            805                 

Other

            292               (1            291   

 

 

Net Cash Provided by (Used in) Investing Activities

     1,769        (2,036            (4,814     (699     (5,780

 

 

Cash Flows From Financing Activities

            

Issuance of debt

            3,049               179        (730     2,498   

Repayment of debt

            (100            (62     100        (62

Issuance of company common stock

     172                             (218     (46

Dividends paid

     (1,819                   (24     24        (1,819

Other

     2        (1,996            630        1,329        (35

 

 

Net Cash Provided by (Used in) Financing Activities

     (1,645     953               723        505        536   

 

 

Effect of Exchange Rate Changes on Cash and Cash Equivalents

                          (47            (47

 

 

Net Change in Cash and Cash Equivalents

            (735     1        (515            (1,249

Cash and cash equivalents at beginning of period

            770        7        4,285               5,062   

 

 

Cash and Cash Equivalents at End of Period

   $        35        8        3,770               3,813   

 

 

 

29


Table of Contents
Item 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

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 49.

The terms “earnings” and “loss” as used in Management’s Discussion and Analysis refer to net income (loss) attributable to ConocoPhillips.

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 had operations and activities in 20 countries, approximately 15,400 employees worldwide and total assets of $96 billion as of June 30, 2016.

Overview

We are an independent E&P company focused on exploring for, developing and producing crude oil and natural gas globally. We have a diverse, low cost of supply resource base and a unique set of producing assets that includes legacy assets in North America, Europe and Asia; North American tight oil assets; resource-rich oil sands assets in Canada; and liquefied natural gas (LNG) assets in Asia Pacific, the Middle East and Alaska. Our value proposition combines unique portfolio attributes with capital allocation principles that include distributions to shareholders, a strong investment grade balance sheet, disciplined growth and a focus on returns. Our value proposition recognizes that future growth could be on an absolute or a per-share basis, consistent with a disciplined approach to business.

The energy landscape continues to be challenged. Global production oversupply caused continued weakness in commodity prices in the first half of 2016, following a year of weak prices in 2015. Ongoing uncertainty around the timing of a price recovery, coupled with tightening credit capacity across the industry, caused us to take actions to preserve our balance sheet strength and mitigate the impacts of possible weak prices in 2016 and 2017.

We reduced our quarterly dividend in February 2016 by 66 percent, to $0.25 per share. In April 2016, we revised our 2016 operating plan, reducing our capital expenditures guidance from $6.4 billion to $5.7 billion, primarily driven by reduced deepwater exploration activity, deferrals and lower costs across the portfolio. We further reduced our capital expenditures guidance to $5.5 billion in July 2016. These actions will allow us to conserve cash throughout the year. During the first quarter of 2016, we issued $3.0 billion of debt and obtained a $1.6 billion three-year term loan to secure sufficient cash and liquidity through the current downturn.

We continue to stay focused on safely executing our capital program and remaining vigilant on costs. We produced 1,546 thousand barrels of oil equivalent per day (MBOED) in the second quarter of 2016, a decrease

 

30


Table of Contents

of 49 MBOED compared with the same period of 2015, as normal field decline, impacts from dispositions, planned downtime and the impact of wildfires in Canada exceeded growth from major projects and development programs and improved well performance. When adjusted for 95 MBOED from dispositions and downtime, production increased 46 MBOED, or 3 percent, compared with the second quarter of 2015. We also saw continued strong operations from our APLNG project in Australia, achieved first production at Foster Creek Phase G, and continue to pursue sustainable operating cost reductions within our business. Operating costs include production and operating expense; selling, general and administrative expense; and exploration general and administrative, geological and geophysical, lease rental and other expense.

Our 2016 capital program is focused on maintaining our asset integrity, completing several projects that are underway and pursuing development programs, primarily around legacy conventional assets. We have significantly reduced activity levels in the North American tight oil plays, including the Eagle Ford, Bakken, Permian, Niobrara and Montney. However, we have retained the flexibility to adjust investment levels in these and other assets, as appropriate.

In the six-month period of 2016, we generated approximately $363 million in proceeds from non-core asset dispositions, including the completion of an asset sale in Alaska in the second quarter of 2016. We have stated an intention to exit deepwater exploration, as well as pursue other non-core dispositions. In July 2016, we signed a sale and purchase agreement for exploration blocks offshore Senegal. We continue to monitor the market and evaluate our assets for opportunities to optimize our portfolio. However, we are not willing to divest properties unless we achieve value.

In July 2016, we announced targeted workforce reductions in certain areas of our business. Approximately 6 percent of our global workforce will be affected. As the analysis is ongoing, it is not reasonably practicable to quantify the financial impact, but the impact could be material to our results of operations in the third quarter of 2016.

We believe we are taking judicious actions across the business to withstand uncertain prices and ongoing volatility. We have exercised significant capital flexibility, lowered our operating cost structure, reduced our dividend, and continued to optimize our asset base. We believe these actions, in combination with our strong execution of the business, will allow us to manage through this current period of low commodity prices and to deliver stronger performance when prices recover.

Basis of Presentation

Effective November 1, 2015, the Other International and historically presented Europe segments were restructured to align with changes to our internal organization structure. The Libya business was moved from the Other International segment to the historically presented Europe segment, which is now renamed Europe and North Africa. Accordingly, results of operations for the Other International and Europe and North Africa segments have been revised for all prior periods presented. There was no impact on our consolidated financial statements, and the impact on our segment presentation is immaterial. For additional information, see Note 19—Segment Disclosures and Related Information, in the Notes to Consolidated Financial Statements.

Business Environment

In the first half of 2014, strong crude oil prices were supported by geopolitical tensions impacting supplies, as well as global oil demand growth. This was followed by an abrupt decline in prices beginning in the third quarter of 2014, as surging production growth from U.S. tight oil and the decision by the Organization of Petroleum Exporting Countries (OPEC) to target market share outweighed fears of supply disruptions. These developments, combined with lower forecasts for global oil demand growth, caused crude oil prices to plummet to near five-year lows at the end of 2014. As global inventories grew due to the ensuing supply surplus, prices continued even lower, and reached a ten-year quarterly low average of $33.89 per barrel for Brent crude oil in the first quarter of 2016. Prices rebounded notably in the second quarter of 2016 due to supply disruptions, lower non-OPEC production, continued healthy demand growth and expectations of a seasonal improvement in demand, but remain lower than the corresponding period of 2015.

 

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Table of Contents

The energy industry has periodically experienced this type of extreme volatility due to fluctuating supply and demand conditions. Commodity prices are the most significant factor impacting our profitability and the related reinvestment of operating cash flows into our business. Among other dynamics that could influence world energy markets and commodity prices are global economic health, supply disruptions or fears thereof caused by civil unrest or military conflicts, actions taken by OPEC or other producers, environmental laws, tax regulations, governmental policies and weather-related changes in demand. North America’s energy landscape has been transformed from resource scarcity to an abundance of supply, primarily due to advances in technology responsible for the rapid growth of tight oil production, successful exploration, and rising production from the Canadian oil sands. Our strategy is to sustainably lower our cost structure and maintain a strong balance sheet while utilizing a diverse and low-cost portfolio that will provide the financial flexibility to withstand challenging business cycles.

Our earnings and operating cash flows generally correlate with industry price levels for crude oil and natural gas, the prices of which are subject to factors external to the company and over which we have no control. The following graph depicts the trend in average benchmark prices for West Texas Intermediate (WTI) crude oil, Dated Brent crude oil and U.S. Henry Hub (HH) natural gas:

 

LOGO

Brent crude oil prices averaged $45.57 per barrel in the second quarter of 2016, a decrease of 26 percent compared with $61.92 per barrel in the second quarter of 2015. Industry crude prices for WTI averaged $45.48 per barrel in the second quarter of 2016, a decrease of 21 percent compared with $57.84 per barrel in the second quarter of 2015. Crude oil prices have remained under pressure in 2016 as global production continues to exceed global demand, as evidenced by continued high inventory levels.

Henry Hub natural gas prices averaged $1.95 per million British thermal units (MMBTU) in the second quarter of 2016, a decrease of 26 percent compared with $2.65 per MMBTU in the second quarter of 2015. Natural gas prices remained under pressure with strong production levels and a warmer-than-expected winter reducing demand below expectations. U.S. underground gas storage inventories have been at or above the top of the five-year range over the past few months.

Our realized bitumen price was $18.11 per barrel in the second quarter of 2016, a decrease of 45 percent compared with $32.84 per barrel in the second quarter of 2015, primarily due to the significant decline in the Western Canada Select benchmark as a result of falling WTI and Brent prices.

Our total average realized price was $27.79 per barrel of oil equivalent (BOE) in the second quarter of 2016, a decrease of 29 percent compared with $39.06 per BOE in the second quarter of 2015, reflecting lower average realized prices for crude oil, natural gas, bitumen and natural gas liquids.

 

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Table of Contents

Key Operating and Financial Summary

Significant items during the second quarter of 2016 included the following:

 

   

Exceeded second-quarter guidance with production of 1,546 MBOED; increasing full-year guidance.

   

Lowering 2016 capital expenditures guidance from $5.7 billion to $5.5 billion.

   

Safely executed second-quarter major turnaround activity in Europe and Alaska; activity ongoing in the third quarter.

   

Achieved first production at Foster Creek Phase G in Canada; Surmont production restored to prior quarter levels after wildfires.

   

On track for first cargo from APLNG Train 2 in Australia and first production from Alder in Europe in the fourth quarter of 2016.

   

Lowered debt by $0.8 billion, compared to the first quarter of 2016.

   

Completed non-core asset sales of $0.2 billion, bringing the six-month 2016 total to $0.4 billion; signed a sale and purchase agreement for exploration blocks offshore Senegal in July.

Outlook

Capital and Production Guidance

Guidance for full-year 2016 capital expenditures has been lowered to $5.5 billion versus prior guidance of $5.7 billion.

We are increasing our full-year 2016 production guidance to 1,540 to 1,570 MBOED reflecting strong year-to-date performance across most of our portfolio. Third-quarter 2016 production guidance is 1,510 to 1,550 MBOED, which reflects significant planned turnaround activity during the quarter.

Marketing Activities

In line with our objective to continuously optimize our portfolio, we are currently marketing certain non-core assets. We expect to generate up to $1 billion in proceeds in 2016 from asset sales.

Reserve Replacement

Proved reserve estimates require economic production based on historical 12-month, first-of-month, average prices and current costs. Therefore, as prices and cost levels change, the estimate of proved reserves also changes. Generally, our proved reserves decrease as prices decline and increase as prices rise. If commodity prices remain near recent levels, significant reductions to our proved reserves can be expected at year-end 2016, primarily related to proved undeveloped reserves associated with the oil sands assets in our Canada segment. However, we do not expect negative price-related reserve revisions to materially impact current plans for development of these assets. Reserve estimates are subject to change based on commodity prices for the remainder of 2016, as well as development and production costs, capital spending levels, timing of project approvals and other factors.

 

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Table of Contents

RESULTS OF OPERATIONS

Unless otherwise indicated, discussion of results for the three- and six-month period ended June 30, 2016, is based on a comparison with the corresponding period of 2015.

Consolidated Results

A summary of the Company’s net income (loss) attributable to ConocoPhillips by business segment follows:

 

                                                           
     Millions of Dollars  
     Three Months Ended
June 30
    Six Months Ended
June 30
 
     2016     2015     2016 &nbs