10-Q 1 d486070d10q.htm FORM 10-Q Form 10-Q
Table of Contents

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

FORM 10-Q

 

 

(Mark One)

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

For the quarterly period ended September 30, 2017

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  ☒     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  ☒    No  ☐

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

 

Large accelerated filer      Accelerated filer  
Non-accelerated filer      Smaller reporting company  
Emerging growth company       

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. [ ]

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

The registrant had 1,195,515,824 shares of common stock, $.01 par value, outstanding at September 30, 2017.

 

 

 


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

     29  

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

     34  

Item 3. Quantitative and Qualitative Disclosures About Market Risk

     58  

Item 4. Controls and Procedures

     58  

Part II—Other Information

  

Item 1. Legal Proceedings

     59  

Item 1A. Risk Factors

     59  

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

     60  

Item 6. Exhibits

     61  

Signature

     62  


Table of Contents

PART I. FINANCIAL INFORMATION

 

Item 1. FINANCIAL STATEMENTS

 

Consolidated Income Statement      ConocoPhillips  

 

                                                           
     Millions of Dollars  
     Three Months Ended
September 30
    Nine Months Ended
September 30
 
     2017     2016     2017     2016  
  

 

 

   

 

 

 

Revenues and Other Income

        

Sales and other operating revenues

   $ 6,688       6,415       20,987       16,884  

Equity in earnings (losses) of affiliates

     196       (60     574       (129

Gain on dispositions

     246       51       2,144       202  

Other income

     65       110       143       149  

 

 

Total Revenues and Other Income

     7,195       6,516       23,848       17,106  

 

 

Costs and Expenses

        

Purchased commodities

     2,926       2,819       9,040       7,046  

Production and operating expenses

     1,224       1,526       3,849       4,325  

Selling, general and administrative expenses

     132       203       423       556  

Exploration expenses

     75       457       724       1,572  

Depreciation, depletion and amortization

     1,608       2,425       5,212       7,001  

Impairments

     6       123       6,475       321  

Taxes other than income taxes

     175       161       604       538  

Accretion on discounted liabilities

     89       108       276       329  

Interest and debt expense

     251       335       872       928  

Foreign currency transaction losses

     5       13       28       12  

Other expense

     51             285        

 

 

Total Costs and Expenses

     6,542       8,170       27,788       22,628  

 

 

Income (loss) before income taxes

     653       (1,654     (3,940     (5,522

Income tax provision (benefit)

     217       (628     (1,549     (1,982

 

 

Net Income (Loss)

     436       (1,026     (2,391     (3,540

Less: net income attributable to noncontrolling interests

     (16     (14     (43     (40

 

 

Net Income (Loss) Attributable to ConocoPhillips

   $ 420       (1,040     (2,434     (3,580

 

 

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

        

Basic

   $ 0.35       (0.84     (1.98     (2.88

Diluted

     0.34       (0.84     (1.98     (2.88

 

 

Dividends Paid Per Share of Common Stock (dollars)

   $ 0.27       0.25       0.80       0.75  

 

 

Average Common Shares Outstanding (in thousands)

        

Basic

     1,212,454       1,245,961       1,230,742       1,245,139  

Diluted

     1,215,341       1,245,961       1,230,742       1,245,139  

 

 

See Notes to Consolidated Financial Statements.

 

1


Table of Contents
Consolidated Statement of Comprehensive Income    ConocoPhillips

 

                                                           
     Millions of Dollars  
     Three Months Ended
September 30
    Nine Months Ended
September 30
 
     2017     2016     2017     2016  
  

 

 

   

 

 

 

Net Income (Loss)

   $ 436       (1,026     (2,391     (3,540

Other comprehensive income (loss)

        

Defined benefit plans

        

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

     (9     (7     (28     (25

Net actuarial gain (loss) arising during the period

     13       (31     (26     (331

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

     49       47       205       229  

Nonsponsored plans*

           2             2  

Income taxes on defined benefit plans

     (18     (2     (52     51  

 

 

Defined benefit plans, net of tax

     35       9       99       (74

 

 

Unrealized holding gain on securities

     551             127        

Income taxes on unrealized holding gain on securities

     (45           (45      

 

 

Unrealized gain on securities, net of tax

     506             82        

 

 

Foreign currency translation adjustments

     509       (82     720       877  

 

 

Foreign currency translation adjustments, net of tax

     509       (82     720       877  

 

 

Other Comprehensive Income (Loss), Net of Tax

     1,050       (73     901       803  

 

 

Comprehensive Income (Loss)

     1,486       (1,099     (1,490     (2,737

Less: comprehensive income attributable to noncontrolling interests

     (16     (14     (43     (40

 

 

Comprehensive Income (Loss) Attributable to ConocoPhillips

   $ 1,470       (1,113     (1,533     (2,777

 

 

*Plans for which ConocoPhillips is not the primary obligor-primarily those administered by equity affiliates.

See Notes to Consolidated Financial Statements.

 

2


Table of Contents
Consolidated Balance Sheet    ConocoPhillips

 

                             
     Millions of Dollars  
     September 30
2017
    December 31
2016
 
  

 

 

 

Assets

    

Cash and cash equivalents

   $ 6,911       3,610  

Short-term investments

     2,696       50  

Accounts and notes receivable (net of allowance of $4 million in 2017 and $5 million in 2016)

     3,222       3,249  

Accounts and notes receivable—related parties

     142       165  

Investment in Cenovus Energy

     2,084        

Inventories

     1,023       1,018  

Prepaid expenses and other current assets

     876       517  

 

 

Total Current Assets

     16,954       8,609  

Investments and long-term receivables

     9,696       21,091  

Loans and advances—related parties

     461       581  

Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $64,115 million in 2017 and $73,075 million in 2016)

     46,669       58,331  

Other assets

     1,081       1,160  

 

 

Total Assets

   $ 74,861       89,772  

 

 

Liabilities

    

Accounts payable

   $ 3,378       3,631  

Accounts payable—related parties

     38       22  

Short-term debt

     1,331       1,089  

Accrued income and other taxes

     1,005       484  

Employee benefit obligations

     528       689  

Other accruals

     851       994  

 

 

Total Current Liabilities

     7,131       6,909  

Long-term debt

     19,673       26,186  

Asset retirement obligations and accrued environmental costs

     7,763       8,425  

Deferred income taxes

     6,262       8,949  

Employee benefit obligations

     1,903       2,552  

Other liabilities and deferred credits

     1,417       1,525  

 

 

Total Liabilities

     44,149       54,546  

 

 

Equity

    

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

    

Issued (2017—1,785,195,738 shares; 2016—1,782,079,107 shares)

    

Par value

     18       18  

Capital in excess of par

     46,595       46,507  

Treasury stock (at cost: 2017—589,679,914 shares; 2016—544,809,771 shares)

     (38,951     (36,906

Accumulated other comprehensive loss

     (5,292     (6,193

Retained earnings

     28,130       31,548  

 

 

Total Common Stockholders’ Equity

     30,500       34,974  

Noncontrolling interests

     212       252  

 

 

Total Equity

     30,712       35,226  

 

 

Total Liabilities and Equity

   $ 74,861       89,772  

 

 

See Notes to Consolidated Financial Statements.

 

3


Table of Contents
Consolidated Statement of Cash Flows      ConocoPhillips  

 

                             
     Millions of Dollars  
     Nine Months Ended
September 30
 
     2017       2016  
  

 

 

 

Cash Flows From Operating Activities

    

Net loss

   $ (2,391     (3,540

Adjustments to reconcile net loss to net cash provided by operating activities

    

Depreciation, depletion and amortization

     5,212       7,001  

Impairments

     6,475       321  

Dry hole costs and leasehold impairments

     435       1,010  

Accretion on discounted liabilities

     276       329  

Deferred taxes

     (2,770     (2,152

Distributions received greater than equity losses (undistributed equity earnings)

     (193     414  

Gain on dispositions

     (2,144     (202

Other

     (367     (50

Working capital adjustments

    

Decrease in accounts and notes receivable

     65       1,112  

Decrease (increase) in inventories

     (15     22  

Decrease (increase) in prepaid expenses and other current assets

     (12     46  

Decrease in accounts payable

     (212     (515

Increase (decrease) in taxes and other accruals

     237       (836

 

 

Net Cash Provided by Operating Activities

     4,596       2,960  

 

 

Cash Flows From Investing Activities

    

Capital expenditures and investments

     (3,074     (3,870

Working capital changes associated with investing activities

     (18     (401

Proceeds from asset dispositions

     13,740       419  

Net purchases of short-term investments

     (2,583     (229

Collection of advances/loans—related parties

     115       108  

Other

     51       61  

 

 

Net Cash Provided by (Used in) Investing Activities

     8,231       (3,912

 

 

Cash Flows From Financing Activities

    

Issuance of debt

           4,594  

Repayment of debt

     (6,594     (839

Issuance of company common stock

     (65     (52

Repurchase of company common stock

     (2,045      

Dividends paid

     (986     (940

Other

     (80     (93

 

 

Net Cash Provided by (Used in) Financing Activities

     (9,770     2,670  

 

 

Effect of Exchange Rate Changes on Cash and Cash Equivalents

     244       4  

 

 

Net Change in Cash and Cash Equivalents

     3,301       1,722  

Cash and cash equivalents at beginning of period

     3,610       2,368  

 

 

Cash and Cash Equivalents at End of Period

   $ 6,911       4,090  

 

 

See Notes to Consolidated Financial Statements.

 

4


Table of Contents
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 2016 Annual Report on Form 10-K.

Note 2—Variable Interest Entities (VIEs)

We hold variable interests in VIEs that have not been consolidated because we are not considered the primary beneficiary. Information on our significant VIEs 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 September 30, 2017, 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 5—Investments, Loans and Long-Term Receivables, and Note 11—Guarantees, for additional information.

Marine Well Containment Company, LLC (MWCC)

MWCC provides well containment equipment and technology and related services in the deepwater U.S. Gulf of Mexico. Its principal activities involve the development and maintenance of rapid-response hydrocarbon well containment systems that are deployable in the Gulf of Mexico on a call-out basis. We have a 10 percent ownership interest in MWCC, and it is accounted for as an equity method investment because MWCC is a limited liability company in which we are a Founding Member and exercise significant influence through our permanent seat on the ten-member Executive Committee responsible for overseeing the affairs of MWCC. In 2016, MWCC executed a $154 million term loan financing arrangement with an external financial institution whose terms required the financing be secured by letters of credit provided by certain owners of MWCC, including ConocoPhillips. In connection with the financing transaction, we issued a letter of credit of $22 million which can be drawn upon in the event of a default by MWCC on its obligation to repay the proceeds of the term loan. The fair value of this letter of credit is immaterial and not recognized on our consolidated balance sheet. MWCC is considered a VIE, as it has entered into arrangements that provide it with additional forms of subordinated financial support. We are not the primary beneficiary and do not consolidate MWCC because we share the power to govern the business and operation of the company and to undertake certain obligations that most significantly impact its economic performance with nine other unaffiliated owners of MWCC.

At September 30, 2017, the carrying value of our equity method investment in MWCC was $141 million. We have not provided any financial support to MWCC other than amounts previously contractually required. Unless we elect otherwise, we have no requirement to provide liquidity or purchase the assets of MWCC.

 

5


Table of Contents

Note 3—Inventories

Inventories consisted of the following:

 

                             
     Millions of Dollars  
     September 30
2017
     December 31
2016
 
  

 

 

 

Crude oil and natural gas

   $ 465        418  

Materials and supplies

     558        600  

 

 
   $ 1,023        1,018  

 

 

Inventories valued on the last-in, first-out (LIFO) basis totaled $297 million and $269 million at September 30, 2017 and December 31, 2016, respectively. The estimated excess of current replacement cost over LIFO cost of inventories was approximately $90 million and $104 million at September 30, 2017 and December 31, 2016, respectively.

Note 4—Assets Held for Sale or Sold

Assets Held for Sale

On June 28, 2017, we signed a definitive agreement with an affiliate of Miller Thomson & Partners LLC to sell our interests in the Barnett for $305 million in cash, subject to customary adjustments. The transaction is subject to specific conditions precedent being satisfied, including regulatory approval, and is expected to close in the fourth quarter of 2017. We recorded a before-tax impairment of $566 million in the second quarter of 2017 to reduce the carrying value of our investment to fair value and an additional impairment of $2 million was recorded in the third quarter of 2017. As of September 30, 2017, our Barnett interests had a net carrying value of approximately $296 million and were considered held for sale resulting in the reclassification of $344 million of properties, plants and equipment (PP&E) to “Prepaid expenses and other current assets” and $49 million of noncurrent liabilities, primarily asset retirement obligations, to “Other accruals” on our consolidated balance sheet. The before-tax loss associated with our interests in the Barnett, including the $566 million and $2 million impairments noted above, was $575 million and $55 million for the nine-month periods ended September 30, 2017 and September 30, 2016, respectively. The Barnett results of operations are reported within our Lower 48 segment.

Assets Sold

On May 17, 2017, we completed the sale of our 50 percent nonoperated interest in the Foster Creek Christina Lake (FCCL) Partnership, as well as the majority of our western Canada gas assets to Cenovus Energy. Consideration for the transaction was $11 billion in cash after customary adjustments, including $600 million related to environmental claims, 208 million Cenovus Energy common shares and a five-year uncapped contingent payment. The cash proceeds are included in the “Cash Flows From Investing Activities” section of our consolidated statement of cash flows. The value of the shares at closing was $1.96 billion based on a price of $9.41 per share on the New York Stock Exchange. The contingent payment, calculated and paid on a quarterly basis, is $6 million Canadian dollars (CAD) for every $1 CAD by which the Western Canada Select (WCS) quarterly average crude price exceeds $52 CAD per barrel.

At closing, the carrying value of our equity investment in FCCL was $8.9 billion. The carrying value of our interest in the western Canada gas assets was $1.9 billion consisting primarily of $2.6 billion of PP&E, partly offset by asset retirement obligations of $585 million and approximately $100 million of environmental and other accruals. A before-tax gain of $1.85 billion was included in the “Gain on disposition” line on our consolidated income statement for the second quarter of 2017. An additional before-tax gain of $281 million was recognized in the third quarter of 2017. We reported before-tax losses of $26 million and $444 million for the western Canada gas producing properties for the nine-month periods ending September 30, 2017 and

 

6


Table of Contents

September 30, 2016, respectively. We reported before-tax equity earnings of $197 million and a before-tax equity loss of $37 million for FCCL for the same periods, respectively. Both FCCL and the western Canada gas assets were reported within our Canada segment.

For more information on the Canada disposition and our investment in Cenovus Energy see Note 6—Investment in Cenovus Energy, Note 14—Fair Value Measurement, and Note 15—Accumulated Other Comprehensive Income (Loss).

On July 31, 2017, we completed the sale of our interests in the San Juan Basin to an affiliate of Hilcorp Energy Company for $2.5 billion in cash after customary adjustments, and recognized a loss on disposition of $22 million. The $2.5 billion of cash proceeds are included in the “Cash Flows From Investing Activities” section of our consolidated statement of cash flows. The transaction includes a contingent payment of up to $300 million. The six-year contingent payment is effective beginning January 1, 2018, and is due annually for the periods in which the monthly U.S. Henry Hub price is at or above $3.20 per million British thermal units.

In the second quarter of 2017, we recorded a before-tax impairment of $3.3 billion to reduce the carrying value of our interests in the San Juan Basin to fair value. At the time of disposition, the San Juan Basin interests had a net carrying value of approximately $2.5 billion, consisting of $2.9 billion of PP&E and $406 million of liabilities, primarily asset retirement obligations. The before-tax loss associated with our interests in the San Juan Basin, including both the $3.3 billion impairment and $22 million loss on disposition noted above, was $3.2 billion and $226 million for the nine-month periods ended September 30, 2017 and September 30, 2016, respectively. The San Juan Basin results of operations are reported within our Lower 48 segment.

On September 29, 2017, we completed the sale of our interest in the Panhandle assets for $178 million in cash after customary adjustments, and recognized a before-tax loss on disposition of $28 million. The proceeds are included in the “Cash Flows From Investing Activities” section of our consolidated statement of cash flows. At the time of the disposition, the carrying value of our interest was $206 million, consisting primarily of $279 million of PP&E and $72 million of asset retirement obligations. Including the $28 million loss on disposition noted above, we reported before-tax losses for the Panhandle properties of $16 million and $28 million for the nine months ended September 30, 2017 and September 30, 2016, respectively. The Panhandle results are reported within our Lower 48 segment.

Note 5—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. All amounts have been drawn from the facility. APLNG made its first principal and interest repayment in March 2017 and will continue to make bi-annual payments until March 2029. At September 30, 2017, a balance of $7.9 billion was outstanding on 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 achieved financial completion. In October 2016, we reached financial completion for Train 1, which reduced our associated guarantee by 60 percent. In August 2017, we reached financial completion for Train 2, which removed the remaining guarantee. 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 2—Variable Interest Entities (VIEs), for additional information.

During the first and second quarters of 2017, the outlook for crude oil prices deteriorated, and as a result of significantly reduced price outlooks, the estimated fair value of our investment in APLNG declined to an amount below carrying value. Based on a review of the facts and circumstances surrounding this decline in

 

7


Table of Contents

fair value, we concluded in the second quarter of 2017 the impairment was other than temporary under the guidance of Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 323, “Investments – Equity Method and Joint Ventures,” and the recognition of an impairment of our investment to fair value was necessary. Accordingly, we recorded a noncash $2,384 million, before- and after-tax impairment in our second-quarter 2017 results. Fair value was estimated based on an internal discounted cash flow model using estimated future production, an outlook of future prices from a combination of exchanges (short-term) and pricing service companies (long-term), costs, a market outlook of foreign exchange rates provided by a third party, and a discount rate believed to be consistent with those used by principal market participants. The impairment was included in the “Impairments” line on our consolidated income statement.

At September 30, 2017, the carrying value of our equity method investment in APLNG was $7,661 million. The balance is included in the “Investments and long-term receivables” line item on our consolidated balance sheet.

FCCL

On May 17, 2017, we completed the sale of our 50 percent nonoperated interest in the FCCL Partnership, as well as the majority of our western Canada gas assets to Cenovus Energy. For additional information on the Canada disposition and our investment in Cenovus Energy, see Note 4—Assets Held for Sale or Sold and Note 6—Investment in Cenovus Energy.

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 September 30, 2017, significant loans to affiliated companies included $581 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 6-–Investment in Cenovus Energy

On May 17, 2017, we completed the sale of our 50 percent nonoperated interest in the FCCL Partnership, as well as the majority of our western Canada gas assets to Cenovus Energy. Consideration for the transaction included 208 million Cenovus Energy common shares. See Note 4—Assets Held for Sale or Sold, for additional information on the Canada disposition.

At closing, the fair value and cost basis of our investment in 208 million Cenovus Energy common shares was $1.96 billion based on a price of $9.41 per share on the New York Stock Exchange. Our ownership approximates to 16.9 percent of issued and outstanding Cenovus common shares, and under an investor agreement with Cenovus Energy, we have agreed not to transfer any of our Cenovus Energy common shares until six months from the closing date (the “Lock-up Termination Date”).

We have classified our investment as an available-for-sale equity security on our consolidated balance sheet and, as of September 30, 2017, our investment is carried at fair value of $2.08 billion, reflecting the closing price of Cenovus Energy shares on the New York Stock Exchange of $10.02 per share. The carrying value reflects a before-tax unrealized gain of $127 million and an after-tax unrealized gain of $82 million over our cost basis of $1.96 billion. The unrealized gain is reported as a component of accumulated other comprehensive loss. See Note 14—Fair Value Measurement, for additional information. Following the Lock-up Termination Date, we intend to decrease our investment over time through market transactions, private agreements or otherwise.

 

8


Table of Contents

Note 7—Suspended Wells and Other Exploration Expenses

The capitalized cost of suspended wells at September 30, 2017, was $872 million, a decrease of $191 million from $1,063 million at year-end 2016. Two suspended wells in Shenandoah in the Gulf of Mexico totaling $94 million, one suspended well in Alaska totaling $17 million, and one suspended well in Malaysia totaling $23 million were charged to dry hole expense during the first nine months of 2017 relating to exploratory well costs capitalized for a period greater than one year as of December 31, 2016.

We reached a settlement agreement on our contract for the Athena drilling rig, initially secured for our four-well commitment program in Angola. As a result of the cancellation, we recorded a before-tax charge of $43 million net in the first quarter of 2017. This charge is included in the “Exploration expenses” line on our consolidated income statement.

Note 8—Impairments

During the three- and nine-month periods ended September 30, 2017 and 2016, we recognized before-tax impairment charges within the following segments:

 

                                                           
     Millions of Dollars  
     Three Months Ended
September 30
     Nine Months Ended
September 30
 
     2017      2016      2017      2016  
  

 

 

    

 

 

 

Alaska

   $ 1               178         

Lower 48

     3        1        3,888        61  

Canada

            60        18        60  

Europe and North Africa

     2        20        7        157  

Asia Pacific and Middle East

            42        2,384        43  

 

 
   $ 6        123        6,475        321  

 

 

In the nine-month period of 2017, our Lower 48 segment included impairments of $3,888 million primarily due to certain developed properties which were written down to fair value less costs to sell. See Note 4—Assets Held for Sale or Sold, for additional information on our dispositions. Additionally, the nine-month period of 2017 included the impairment of our APLNG investment reported within the Asia Pacific and Middle East segment. For more information, see the “APLNG” section of Note 5—Investments, Loans and Long-Term Receivables. The nine-month period also included an impairment in our Alaska segment in the first quarter of 2017 of $174 million for the associated PP&E carrying value of our small interest in a nonoperated producing property.

In October 2017, we expect to record an estimated $60 million before-tax impairment of a gas processing plant in Norway, primarily due to restructured ownership and a change in commercial premises. This impairment will be reflected in our year-end results within our Europe and North Africa segment.

In the three- and nine-month periods ended September 30, 2016, our Canada and Asia Pacific and Middle East segments included impairments of $60 million and $42 million, respectively, primarily related to certain developed properties in central Alberta and offshore Indonesia, which were written down to fair value less costs to sell. Our Europe and North Africa segment included impairments of $20 million in the three-month period ended September 30, 2016, primarily as a result of a canceled project and lower natural gas prices, both in the United Kingdom. In the nine-month period of 2016, our Europe and North Africa segment included impairments of $157 million, primarily as a result of lower natural gas prices in the United Kingdom. Our Lower 48 segment included impairments of $61 million before-tax in the nine-month period of 2016, primarily as a result of lower natural gas prices and increased asset retirement obligation estimates.

 

9


Table of Contents

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 nine-month periods of 2017 and 2016 were aligned with our decision announced in 2015 to reduce deepwater exploration spending.

In the first quarter of 2017, we recorded a before-tax impairment of $51 million for the associated carrying value of capitalized undeveloped leasehold costs of Shenandoah in deepwater Gulf of Mexico following the suspension of appraisal activity by the operator.

In the second quarter of 2016, we recorded a $203 million before-tax impairment for the associated carrying value of our Gibson and Tiber undeveloped leaseholds in deepwater Gulf of Mexico. 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 the majority of a $79 million impairment in deepwater Gulf of Mexico, mainly as a result of changes in the estimated market value following the completion of an initial marketing effort.

Note 9—Debt

As of September 30, 2017, our revolving credit facility, expiring in June 2019, was $6.75 billion. The credit facility supports two commercial paper programs: 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 September 30, 2017 and December 31, 2016, we had no direct outstanding borrowings under the revolving credit facility and no letters of credit. We had no commercial paper outstanding at September 30, 2017 or December 31, 2016, under both the ConocoPhillips and the ConocoPhillips Qatar Funding Ltd. commercial paper programs. 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 September 30, 2017.

In the first quarter of 2017, we made a prepayment of $805 million on our floating rate term loan facility due in 2019. In the third quarter of 2017, we prepaid the remaining balance of $645 million.

During the nine-month period of 2017, we redeemed a total $4.8 billion of debt as described below.

In the second quarter of 2017, we redeemed $3.0 billion of debt across the following instruments:

 

   

6.65% Debentures due 2018 with principal of $297 million.

   

5.75% Notes due 2019 with principal of $2.25 billion (partial redemption of $1.7 billion).

   

6.00% Notes due 2020 with principal of $1.0 billion.

In the third quarter of 2017, we redeemed $1.8 billion of debt across the following instruments:

 

   

5.20% Notes due 2018 with principal of $500 million.

   

1.50% Notes due 2018 with principal of $750 million.

   

5.75% Notes due 2019 with principal of $550 million.

We incurred premiums above book value to redeem the debt instruments of $234 million and $50 million in the second and third quarter of 2017, respectively. These costs are reported in the “Other expense” line on our consolidated income statement.

 

10


Table of Contents

In October 2017, we gave notice to make a partial redemption of $250 million on the $1.25 billion 4.20% Notes due in 2021. The prepayment will occur in the fourth quarter of 2017, and we expect to incur approximately $20 million in premiums above book value, subject to pricing, related to this redemption when paid.

At September 30, 2017, 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 nine months of 2017 and 2016 was as follows:

 

                                                                                         
     Millions of Dollars  
     2017     2016  
     Common
Stockholders’
Equity
    Non-
Controlling
Interest
    Total
Equity
    Common
Stockholders’
Equity
    Non-
Controlling
Interest
    Total
Equity
 
  

 

 

   

 

 

 

Balance at January 1

   $ 34,974       252       35,226       39,762       320       40,082  

Net income (loss)

     (2,434     43       (2,391     (3,580     40       (3,540

Dividends

     (986           (986     (940           (940

Repurchase of company common stock

     (2,045           (2,045                  

Distributions to noncontrolling interests

           (84     (84           (75     (75

Other changes, net*

     991       1       992       928       1       929  

 

 

Balance at September 30

   $ 30,500       212       30,712       36,170       286       36,456  

 

 

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

Note 11—Guarantees

At September 30, 2017, 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 September 30, 2017, 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 September 2017 exchange rates:

 

   

We 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. Our maximum potential amount of future payments related to this guarantee became immaterial in the second quarter of 2017.

 

11


Table of Contents
   

We issued a construction completion guarantee related to the third-party project financing secured by APLNG. In October 2016, we reached financial completion for Train 1, releasing a portion of our guarantee. In August 2017, the two-train project finance lenders’ test was completed, releasing the remaining guarantee.

 

   

During the third quarter of 2016, we issued a guarantee to facilitate the withdrawal of our pro-rata portion of the funds in a project finance reserve account. We estimate the remaining term of this guarantee is 12 years. Our maximum exposure under this guarantee is approximately $200 million and may become payable if an enforcement action is commenced by the project finance lenders against APLNG. At September 30, 2017, the carrying value of this guarantee was approximately $14 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 up to 25 years. Our maximum potential liability for future payments, or cost of volume delivery, under these guarantees is estimated to be $1 billion ($1.75 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 28 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 $780 million, which consist primarily of guarantees of the residual value of leased office buildings, guarantees of the residual value of leased corporate aircraft, and a guarantee for our portion of a joint venture’s project finance reserve accounts. These guarantees have remaining terms of up to six 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 September 30, 2017, was approximately $100 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 September 30, 2017, 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.

 

12


Table of Contents

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 $1.28 billion. At September 30, 2017, the carrying value of this guarantee is approximately $98 million and the remaining term is seven years. Because Phillips 66 has indemnified us for losses incurred under this guarantee, we have recorded an indemnification asset from Phillips 66 of 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

 

13


Table of Contents

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.

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 September 30, 2017, our balance sheet included a total environmental accrual of $182 million, compared with $247 million at December 31, 2016, 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 September 30, 2017, we had performance obligations secured by letters of credit of $286 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. On January 17, 2017, the Tribunal reconfirmed the decision that the expropriation was unlawful. A separate arbitration phase is currently proceeding to determine the damages owed to ConocoPhillips for Venezuela’s actions. Separate arbitrations for contractual compensation against PDVSA are also pending before International Chamber of Commerce (ICC) arbitration tribunals. In addition,

 

14


Table of Contents

ConocoPhillips brought fraudulent transfer actions in the U.S. District Court of Delaware, alleging that PDVSA has taken actions to improperly expatriate assets from the United States to Venezuela in an effort to avoid judgment creditors.

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 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. In February 2017, the tribunal unanimously awarded Burlington $380 million for Ecuador’s unlawful expropriation and breach of the U.S.-Ecuador bilateral investment treaty. The tribunal also issued a separate decision finding Ecuador to be entitled to $42 million for limited environmental and infrastructure impacts associated with the operations of Burlington and its co-venturer. Ecuador filed a request for annulment of this decision with ICSID, triggering a provisional stay of enforcement of the award. On August 31, the ICSID Annulment Committee issued a decision terminating the provisional stay. The annulment proceeding is ongoing.

In December 2016, ConocoPhillips Angola filed a notice of arbitration against Sonangol E.P. under the Block 36 Production Sharing Contract relating to disputes arising thereunder. The arbitration is being conducted under the United Nations Commission on International Trade Laws (UNCITRAL) rules using a three-person tribunal. The arbitration is ongoing.

In June 2017, FAR Ltd. initiated arbitration before the ICC against ConocoPhillips Senegal B.V. in connection with the sale of ConocoPhillips Senegal B.V. to Woodside Energy Holdings (Senegal) Limited in 2016. The arbitral tribunal is in the process of being constituted.

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.

 

15


Table of Contents

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  
     September 30
2017
     December 31
2016
 
  

 

 

 

Assets

     

Prepaid expenses and other current assets

   $ 170        268  

Other assets

     32        44  

Liabilities

     

Other accruals

     167        300  

Other liabilities and deferred credits

     23        34  

 

 

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
September 30
     Nine Months Ended
September 30
 
     2017     2016      2017     2016  
  

 

 

    

 

 

 

Sales and other operating revenues

   $ 17       11        120       (155

Other income

     (1     1        (1     (1

Purchased commodities

     (19     7        (88     136  

 

 

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

 

                             
     Open Position
Long/(Short)
 
     September 30
2017
    December 31
2016
 
  

 

 

 
    

Commodity

    

Natural gas and power (billions of cubic feet equivalent)

    

Fixed price

     (33     (31

Basis

     42       2  

 

 

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.

 

16


Table of Contents

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  
     September 30
2017
     December 31
2016
 
  

 

 

 

Assets

     

Prepaid expenses and other current assets

   $ 1        1  

Liabilities

     

Other accruals

            168  

 

 

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
September 30
     Nine Months Ended
September 30
 
     2017     2016      2017      2016  
  

 

 

    

 

 

 

Foreign currency transaction (gains) losses

   $ (1     35        2        218  

 

 

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

 

                                            
     In Millions
Notional Currency
 
     September 30
2017
     December 31
2016
 
  

 

 

Sell U.S. dollar, buy other currencies*

   USD      26        13  

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

   USD             25  

Buy British pound, sell other currencies***

   GBP      3        1,069  

Sell British pound, buy Norwegian krone

   GBP             51  

 

 

    *Primarily Canadian dollar.

  **Primarily British pound.

***Primarily Euro and Canadian dollar.

Financial Instruments

We invest excess cash in financial instruments with maturities based on our cash forecasts for the various currency pools we manage. The maturities of these investments may from time to time extend beyond 90 days. The types of financial instruments in which we currently invest include:

 

   

Time deposits: Interest bearing deposits placed with approved financial institutions.

   

Commercial paper: Unsecured promissory notes issued by a corporation, commercial bank or government agency purchased at a discount to mature at par.

These financial instruments appear in the “Cash and cash equivalents” line of our consolidated balance sheet if the maturities at the time we made the investments were 90 days or less; otherwise, these financial instruments are included in the “Short-term investments” line on our consolidated balance sheet.

 

17


Table of Contents
                                                           
     Millions of Dollars  
     Carrying Amount  
     Cash and Cash Equivalents      Short-Term Investments  
     September 30
2017
     December 31
2016
     September 30
2017
     December 31
2016
 
  

 

 

 

Cash

   $ 925        623                

Time deposits

           

Remaining maturities from 1 to 90 days

     5,462        2,987        1,103        39  

Remaining maturities from 91 to 180 days

                   74        11  

Commercial paper

           

Remaining maturities from 1 to 90 days

     524               1,320         

Remaining maturities from 91 to 180 days

                   199         

 

 
   $ 6,911        3,610        2,696        50  

 

 

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, government 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; 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 September 30, 2017 and December 31, 2016, was $39 million and $42 million, respectively. For these instruments, no collateral was posted as of September 30, 2017 or December 31, 2016. If our credit rating had been downgraded below investment grade on September 30, 2017, we would be required to post $39 million of additional collateral, either with cash or letters of credit.

 

18


Table of Contents

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 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 2017 or 2016.

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. This also includes our investment in common shares of Cenovus Energy, currently subject to a trading restriction, which is valued using quotes for shares on the New York Stock Exchange. 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.

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  
     September 30, 2017      December 31, 2016  
     Level 1      Level 2      Level 3      Total      Level 1      Level 2      Level 3      Total  
  

 

 

    

 

 

 

Assets

                       

Investment in Cenovus Energy

   $        2,084               2,084                              

Commodity derivatives

     109        69        24        202        194        96        22        312  

 

 

Total assets

   $ 109        2,153        24        2,286        194        96        22        312  

 

 

Liabilities

                       

Commodity derivatives

   $ 112        61        17        190        207        105        22        334  

 

 

Total liabilities

   $ 112        61        17        190        207        105        22        334  

 

 

 

19


Table of Contents

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
 
  

 

 

 

September 30, 2017

                 

Assets

   $ 202        118        84        4        4        76  

Liabilities

     190        118        72        9        3        60  

 

 

December 31, 2016

                 

Assets

   $ 312        221        91               5        86  

Liabilities

     334        221        113        12        12        89  

 

 

At September 30, 2017 and December 31, 2016, 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:

 

                                                           
     Millions of Dollars  
            Fair Value
Measurements Using
 
     Fair Value      Level 1
Inputs
     Level 3
Inputs
    

Before-

Tax Loss

 
  

 

 

    

 

 

    

 

 

    

 

 

 

June 30, 2017 (remeasurement date)

           

Net PP&E (held for sale)

   $ 2,830        2,830               3,882  

Cost and equity method investments

     7,656               7,656        2,384  

 

 

During the second quarter of 2017, net PP&E held for sale was written down to fair value, less costs to sell. The fair value of each asset was determined by its negotiated selling price. For additional information see Note 4—Assets Held for Sale or Sold.

During the second quarter of 2017, our equity method investment in APLNG was determined to have fair value below its carrying value, and the impairment was considered to be other than temporary. See the “APLNG” section of Note 5Investments, Loans and Long-Term Receivables, for information on the impairment of our APLNG investment.

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.

 

20


Table of Contents
   

Investment in Cenovus Energy shares: See Note 6—Investment in Cenovus Energy, for a discussion of the carrying value and fair value of our investment in Cenovus Energy shares.

   

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 5—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  
     September 30      December 31      September 30      December 31  
     2017      2016      2017      2016  
  

 

 

    

 

 

 

Financial assets

           

Investment in Cenovus Energy

   $ 2,084               2,084         

Commodity derivatives

     80        91        80        91  

Total loans and advances—related parties

     583        701        583        701  

Financial liabilities

           

Total debt, excluding capital leases

     20,181        26,423        23,451        29,307  

Commodity derivatives

     63        101        63        101  

 

 

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
    Net
Unrealized
Gain on
Securities
     Foreign
Currency
Translation
    Accumulated
Other
Comprehensive
Income (Loss)
 
  

 

 

 

December 31, 2016

   $ (547            (5,646     (6,193

Other comprehensive income

     99       82        720       901  

 

 

September 30, 2017

   $ (448 )      82        (4,926     (5,292

 

 

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

 

21


Table of Contents

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

 

                                                           
     Millions of Dollars  
     Three Months Ended
September 30
     Nine Months Ended
September 30
 
     2017      2016      2017      2016  
  

 

 

    

 

 

 

Defined benefit plans

   $ 26        27        116        132  

 

 
Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of:    $ 14        13        61        72  

See Note 17—Employee Benefit Plans, for additional information.

Note 16—Cash Flow Information

 

                             
     Millions of Dollars  
     Nine Months Ended  
     September 30  
     2017       2016  
  

 

 

   

 

 

 

Cash Payments (Receipts)

    

Interest

   $ 918       854  

Income taxes*

     574       (339

 

 

Net Sales (Purchases) of Short-Term Investments

    

Short-term investments purchased

   $ (4,999     (1,704

Short-term investments sold

     2,416       1,475  

 

 
   $ (2,583     (229

 

 

*Net of $569 million in 2016 related to refunds received from the Internal Revenue Service.

During the first quarter of 2017, we recognized a $180 million adverse cash impact from the settlement of cross-currency swap transactions which is included in the “Cash Flows From Operating Activities” section of our consolidated statement of cash flow.

 

22


Table of Contents

Note 17—Employee Benefit Plans

Pension and Postretirement Plans

 

                                                                                         
     Millions of Dollars  
     Pension Benefits     Other Benefits  
     2017     2016     2017     2016  
  

 

 

   

 

 

   

 

 

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

 

 

   

 

 

   

 

 

   

 

 

     

Components of Net Periodic Benefit Cost

            

Three Months Ended September 30

            

Service cost

   $ 21       20       27       19              

Interest cost

     29       27       32       30       3       3  

Expected return on plan assets

     (32     (41     (34     (39            

Amortization of prior service cost (credit)

     1       (1     2       (1     (9     (9

Recognized net actuarial loss (gain)

     17       12       22       6       (1      

Settlements

     21             22                    

Curtailment Loss

                 14                   1  

 

 

Net periodic benefit cost

   $ 57       17       85       15       (7     (5

 

 

Nine Months Ended September 30

            

Service cost

   $ 67       59       82       59       1       1  

Interest cost

     90       78       104       93       7       10  

Expected return on plan assets

     (97     (119     (112     (121            

Amortization of prior service cost (credit)

     3       (4     4       (4     (27     (26

Recognized net actuarial loss (gain)

     53       36       64       20       (2     (1

Settlements

     118             149                    

Curtailment Loss

                 14                   1  

 

 

Net periodic benefit cost

   $ 234       50       305       47       (21     (15

 

 

During the first nine months of 2017, we contributed $783 million to our domestic benefit plans and $89 million to our international benefit plans. In 2017, we expect to contribute approximately $800 million to our domestic qualified and nonqualified pension and postretirement benefit plans and $120 million to our international qualified and nonqualified pension and postretirement benefit plans.

We recognized a proportionate share of prior actuarial losses from other comprehensive income as pension settlement expense of $21 million and $118 million during the three- and nine-month periods ended September 30, 2017, respectively. In conjunction with the recognition of pension settlement expense, the fair market values of U.S. 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 as of September 30, 2017. As part of the remeasurement, the expected rate of return on the U.S. qualified pension plan assets was reduced from 6.8 percent at January 1, 2017, to 5.8 percent at September 30, 2017.

 

23


Table of Contents

Severance Accrual

As a result of selling our 50 percent nonoperated interest in the FCCL Partnership and the majority of our western Canada gas assets, as well as our interests in the San Juan Basin, a reduction in our overall employee workforce began during the second quarter of 2017. Severance accruals of $7 million and $62 million were recorded during the three- and nine-month periods ended September 30, 2017, respectively. The following table summarizes our severance accrual activity for the nine-month period ended September 30, 2017:

 

              
     Millions of Dollars  

Balance at December 31, 2016

   $ 80  

Accruals

     62  

Benefit payments

     (84

Foreign currency translation adjustments

     2  

 

 

Balance at September 30, 2017

   $ 60  

 

 

Of the remaining balance at September 30, 2017, $36 million is classified as short-term.

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
September 30
    Nine Months Ended
September 30
 
     2017     2016     2017     2016  
  

 

 

   

 

 

 

Operating revenues and other income

   $ 24       41       83       96  

Purchases

     26       26       74       75  

Operating expenses and selling, general and administrative expenses

     16       20       42       48  

Net interest (income) expense*

     (4     (3     (10     (9

 

 

*We paid interest to, or received interest from, various affiliates. See Note 5—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.

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.

 

24


Table of Contents

Analysis of Results by Operating Segment

 

                                                           
     Millions of Dollars  
     Three Months Ended
September 30
    Nine Months Ended
September 30
 
     2017     2016     2017     2016  
  

 

 

   

 

 

 

Sales and Other Operating Revenues

        

Alaska

   $ 932       925       3,010       2,639  

 

 

Lower 48

     3,102       2,993       9,422       7,533  

Intersegment eliminations

     (2     (3     (7     (15

 

 

Lower 48

     3,100       2,990       9,415       7,518  

 

 

Canada

     699       615       2,357       1,431  

Intersegment eliminations

     (155     (73     (330     (138

 

 

Canada

     544       542       2,027       1,293  

 

 

Europe and North Africa

     1,110       946       3,564       2,605  

Asia Pacific and Middle East

     959       942       2,877       2,676  

Corporate and Other

     43       70       94       153  

 

 

Consolidated sales and other operating revenues

   $ 6,688       6,415       20,987       16,884  

 

 

Net Income (Loss) Attributable to ConocoPhillips

        

Alaska

   $ 103       59       291       204  

Lower 48

     (97     (491     (2,995     (2,082

Canada

     280       (314     2,607       (783

Europe and North Africa

     85       163       379       132  

Asia Pacific and Middle East

     396       (87     (1,540     (20

Other International

     (20     (47     (77     (100

Corporate and Other

     (327     (323     (1,099     (931

 

 

Consolidated net income (loss) attributable to ConocoPhillips

   $ 420       (1,040     (2,434     (3,580

 

 

 

                             
     Millions of Dollars  
     September 30
2017
     December 31
2016
 
  

 

 

 

Total Assets

     

Alaska

   $ 12,094        12,314  

Lower 48

     14,376        22,673  

Canada

     6,281        17,548  

Europe and North Africa

     12,066        11,727  

Asia Pacific and Middle East

     17,094        20,451  

Other International

     122        97  

Corporate and Other

     12,828        4,962  

 

 

Consolidated total assets

   $ 74,861        89,772  

 

 

 

25


Table of Contents

Note 20—Income Taxes

Our effective tax rates for the third quarter and nine-month period ended September 30, 2017, were 33 percent and 39 percent, respectively, compared with 38 percent and 36 percent for the same periods of 2016. The amounts of U.S. and foreign income (loss) from continuing operations before income taxes, with a reconciliation of tax at the federal statutory rate with the provision for income taxes were:

 

                                                                                                                       
     Millions of Dollars     Percent of Pre-Tax Income (Loss)  
     Three Months Ended
September 30
    Nine Months Ended
September 30
    Three Months Ended
September 30
    Nine Months Ended
September 30
 
     2017     2016     2017     2016     2017     2016     2017     2016  
  

 

 

   

 

 

   

 

 

   

 

 

 

Income (loss) from continuing operations before income taxes

                

United States

   $ (197     (1,001     (5,259     (3,965     (30.2 )%      60.5       133.5       71.8  

Foreign

     850       (653     1,319       (1,557     130.2       39.5       (33.5     28.2  

 

 
   $ 653       (1,654     (3,940     (5,522     100.0     100.0       100.0       100.0  

 

 

Federal statutory income tax

   $ 228       (578     (1,379     (1,932     34.9     34.9       35.0       35.0  

Non-U.S. effective tax rates

     137       147       503       320       21.0       (8.9     (12.8     (5.8

U.K. rate change

           (138           (138           8.3             2.5  

Canada disposition

     (8           (1,176           (1.2           29.8        

Recovery of outside basis

     (118     (15     (957     (38     (18.1     0.9       24.3       0.7  

Adjustment to tax reserves

     (17           764             (2.6           (19.4      

APLNG impairment

                 834                         (21.2      

State income tax

     14       (15     (74     (126     2.1       0.9       1.9       2.3  

Enhanced oil recovery credit

     (5     (28     (49     (62     (0.8     1.7       1.2       1.1  

Other

     (14     (1     (15     (6     (2.1     0.2       0.4       0.1  

 

 
   $ 217       (628     (1,549     (1,982     33.2     38.0       39.3       35.9  

 

 

Our effective tax rate for the three- and nine-month periods ended September 30, 2017, was favorably impacted by a tax benefit of $114 million related to our prior decision to exit Nova Scotia deepwater exploration. This benefit is included in the “Recovery of Outside Tax Basis” line of the table above.

The impairment of our APLNG investment in the second quarter of 2017 did not generate a tax benefit. See the “APLNG” section of Note 5—Investments, Loans and Long-Term Receivables, for information on the impairment of our APLNG investment.

Our effective tax rate for the nine-month period ended September 30, 2017, was favorably impacted by a tax benefit of $1,176 million associated with our Canada disposition. The benefit was primarily associated with a deferred tax recovery related to the Canadian capital gains exclusion component of the transaction and the recognition of previously unrealizable Canadian capital asset tax basis. The disposition, along with the associated restructuring of our Canadian operations, may generate an additional tax benefit of $822 million related to the recovery of outside basis. However, since we believe it is not likely we will receive a corresponding cash tax savings of this amount, the benefit has been offset by a full reserve. See Note 4—Assets Held for Sale or Sold, for additional information on our Canada disposition.

In the United Kingdom, legislation was enacted on September 15, 2016, to decrease the overall U.K. upstream corporation tax rate from 50 percent to 40 percent effective January 1, 2016. As a result, a $138 million net tax benefit resulting from re-measurement of deferred tax liabilities at January 1, 2016, and application of the new rate through September 30, 2016, is reflected in the “Income tax benefit” line on our consolidated income statement.

 

26


Table of Contents

Note 21—New Accounting Standards

In May 2014, the FASB issued Accounting Standards Update (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,” in May 2016 by the provisions of ASU No. 2016-12, “Narrow-Scope Improvements and Practical Expedients,” and in December 2016 by the provisions of ASU No. 2016-20, “Technical Corrections and Improvements to Topic 606, Revenue From Contracts With Customers.”

We will adopt the provisions of ASU No. 2014-09, as amended, with effect from January 1, 2018, and have elected not to early adopt the standard. We intend to adopt the new standard using the modified retrospective approach which we will apply only to contracts within the scope of the standard that are not complete at the date of initial application. Under this approach, we will apply the guidance retrospectively only to the most current period presented in the financial statements. We continue to assess the impact of adoption of the standard on our current accounting policies and revenue-related disclosures. The impact to our financial statements is expected to be immaterial.

In January 2016, the FASB issued ASU No. 2016-01, “Recognition and Measurement of Financial Assets and Financial Liabilities” (ASU No. 2016-01), to meet its objective of providing more decision-useful information about financial instruments. The ASU, among other things, requires entities to record the changes in fair value of equity investments, other than investments accounted for using the equity method, within net income. Under this ASU, entities will no longer be able to recognize unrealized holding gains and losses on available-for-sale securities in other comprehensive income. The ASU also requires additional disclosures relating to fair value measurement categories for financial assets and liabilities and eliminates certain disclosure requirements related to financial instruments measured at amortized cost. ASU No. 2016-01 is effective for interim and annual periods beginning after December 15, 2017, and the ASU should be adopted using a cumulative-effect adjustment to retained earnings as of the date of adoption.

Upon adoption of the standard, we will make a cumulative-effect adjustment to reclassify the accumulated unrealized holding gains and losses related to our investment in Cenovus Energy from other comprehensive income to retained earnings, and from the date of adoption, we will begin reporting the changes in the fair value of our investment within net income. The impact on our consolidated financial statements and disclosures will depend on the amount of accumulated unrealized holding gains and losses recognized in other comprehensive income at December 31, 2017, and changes in the fair value of our investment in Cenovus Energy subsequent to that date. For additional information on our investment in Cenovus Energy, see Note 6—Investment in Cenovus Energy, Note 14—Fair Value Measurement, and Note 15—Accumulated Other Comprehensive Income (Loss).

 

27


Table of Contents

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 plan to adopt ASU No. 2016-02 effective January 1, 2019, and continue to evaluate the ASU to determine the impact of adoption on our consolidated financial statements and disclosures, accounting policies and systems, business processes, and internal controls. While our evaluation of ASU No. 2016-02 and related implementation activities are ongoing, we expect the adoption of the ASU to have a material impact on our consolidated financial statements and disclosures.

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.

 

28


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/or 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 May 2017, ConocoPhillips Company received a $9.8 billion return of capital from a nonguarantor subsidiary to settle certain accumulated intercompany balances. The transaction had no impact on our consolidated financial statements.

In September 2017, ConocoPhillips received a $5.0 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.

 

29


Table of Contents
                                                                                         
     Millions of Dollars  
     Three Months Ended September 30, 2017  
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

   $       2,997             3,691             6,688  

Equity in earnings (losses) of affiliates

     486       348             119       (757     196  

Gain on dispositions

           879             (633           246  

Other income

           12             53             65  

Intercompany revenues

     10       77       43       774       (904      

 

 

Total Revenues and Other Income

     496       4,313       43       4,004       (1,661     7,195  

 

 

Costs and Expenses

            

Purchased commodities

           2,666             1,001       (741     2,926  

Production and operating expenses

           221             1,004       (1     1,224  

Selling, general and administrative expenses

     2       119             11             132  

Exploration expenses

           30             45             75  

Depreciation, depletion and amortization

           203             1,405             1,608  

Impairments

           1             5             6  

Taxes other than income taxes

           29             146             175  

Accretion on discounted liabilities

           8             81             89  

Interest and debt expense

     86       169       37       121       (162     251  

Foreign currency transaction (gains) losses

     (27     1       77       (46           5  

Other expenses

     50       1                         51  

 

 

Total Costs and Expenses

     111       3,448       114       3,773       (904     6,542  

 

 

Income (Loss) before income taxes

     385       865       (71     231       (757     653  

Income tax provision (benefit)

     (35     379       6       (133           217  

 

 

Net income (loss)

     420       486       (77     364       (757     436  

Less: net income attributable to noncontrolling interests

                       (16           (16

 

 

Net Income (Loss) Attributable to ConocoPhillips

   $ 420       486       (77     348       (757     420  

 

 

Comprehensive Income (Loss) Attributable to ConocoPhillips

   $ 1,470       1,536       22       864       (2,422     1,470  

 

 
Income Statement    Three Months Ended September 30, 2016  

Revenues and Other Income

            

Sales and other operating revenues

   $       2,933             3,482             6,415  

Equity in losses of affiliates

     (958     (397           (26     1,321       (60

Gain on dispositions

           11             40             51  

Other income

     1       3             106             110  

Intercompany revenues

     18       71       60       793       (942      

 

 

Total Revenues and Other Income

     (939     2,621       60       4,395       379       6,516  

 

 

Costs and Expenses

            

Purchased commodities

           2,563             1,024       (768     2,819  

Production and operating expenses

           324             1,207       (5     1,526  

Selling, general and administrative expenses

     2       158             43             203  

Exploration expenses

           192             265             457  

Depreciation, depletion and amortization

           351             2,074             2,425  

Impairments

                       123             123  

Taxes other than income taxes

           26             135             161  

Accretion on discounted liabilities

           11             97             108  

Interest and debt expense

     135       159       56       154       (169     335  

Foreign currency transaction (gains) losses

     8             (26     31             13  

 

 

Total Costs and Expenses

     145       3,784       30       5,153       (942     8,170  

 

 

Income (Loss) before income taxes

     (1,084     (1,163     30       (758     1,321       (1,654

Income tax benefit

     (44     (205     (4     (375           (628

 

 

Net income (loss)

     (1,040     (958     34       (383     1,321       (1,026

Less: net income attributable to noncontrolling interests

                       (14           (14

 

 

Net Income (Loss) Attributable to ConocoPhillips

   $ (1,040     (958     34       (397     1,321       (1,040

 

 

Comprehensive Loss Attributable to ConocoPhillips

   $ (1,113     (1,031     (10     (460     1,501       (1,113

 

 

 

30


Table of Contents
                                                                                         
     Millions of Dollars  
     Nine Months Ended September 30, 2017  
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

   $       9,066             11,921             20,987  

Equity in earnings (losses) of affiliates

     (2,092     (776           432       3,010       574  

Gain on dispositions

           908             1,236             2,144  

Other income

     1       27             115             143  

Intercompany revenues

     39       222       126       2,360       (2,747      

 

 

Total Revenues and Other Income

     (2,052     9,447       126       16,064       263       23,848  

 

 

Costs and Expenses

            

Purchased commodities

           8,068             3,229       (2,257     9,040  

Production and operating expenses

           501             3,351       (3     3,849  

Selling, general and administrative expenses

     8       365             55       (5     423  

Exploration expenses

           435             289             724  

Depreciation, depletion and amortization

           658             4,554             5,212  

Impairments

           1,075             5,400             6,475  

Taxes other than income taxes

           114             490             604  

Accretion on discounted liabilities

           28             248             276  

Interest and debt expense

     340       505       110       399       (482     872  

Foreign currency transaction (gains) losses

     (49     3       145       (71           28  

Other expense

     267       18                         285  

 

 

Total Costs and Expenses

     566       11,770       255       17,944       (2,747     27,788  

 

 

Loss before income taxes

     (2,618     (2,323     (129     (1,880     3,010       (3,940

Income tax provision (benefit)

     (184     (231     12       (1,146           (1,549

 

 

Net loss

     (2,434     (2,092     (141     (734     3,010       (2,391

Less: net income attributable to noncontrolling interests

                       (43           (43

 

 

Net Loss Attributable to ConocoPhillips

   $ (2,434     (2,092     (141     (777     3,010       (2,434

 

 

Comprehensive Income (Loss) Attributable to ConocoPhillips

   $ (1,533     (1,191     39       (37     1,189       (1,533

 

 
Income Statement    Nine Months Ended September 30, 2016  

Revenues and Other Income

            

Sales and other operating revenues

   $       7,289             9,595             16,884  

Equity in earnings of affiliates

     (3,388     (1,168           (325     4,752       (129

Gain on dispositions

           96             106             202  

Other income (loss)

     1       (2           150             149  

Intercompany revenues

     62       220       176       2,246       (2,704      

 

 

Total Revenues and Other Income

     (3,325     6,435       176       11,772       2,048       17,106  

 

 

Costs and Expenses

            

Purchased commodities

           6,409             2,585       (1,948     7,046  

Production and operating expenses

           1,065             3,502       (242     4,325  

Selling, general and administrative expenses

     7       448             107       (6     556  

Exploration expenses

           1,174             398             1,572  

Depreciation, depletion and amortization

           914             6,087             7,001  

Impairments

           41             280             321  

Taxes other than income taxes

           122             416             538  

Accretion on discounted liabilities

           35             294             329  

Interest and debt expense

     385       457       168       426       (508     928  

Foreign currency transaction (gains) losses

     (34     2       207       (163           12  

 

 

Total Costs and Expenses

     358       10,667       375       13,932       (2,704     22,628  

 

 

Loss before income taxes

     (3,683     (4,232     (199     (2,160     4,752       (5,522

Income tax provision (benefit)

     (103     (844     (3     (1,032           (1,982

 

 

Net loss

     (3,580     (3,388     (196     (1,128     4,752       (3,540

Less: net income attributable to noncontrolling interests

                       (40           (40

 

 

Net Loss Attributable to ConocoPhillips

   $ (3,580     (3,388     (196     (1,168     4,752       (3,580

 

 

Comprehensive Loss Attributable to ConocoPhillips

   $ (2,777     (2,585     (6     (230     2,821       (2,777

 

 

 

31


Table of Contents
                                                                                         
     Millions of Dollars  
     September 30, 2017  
Balance Sheet    ConocoPhillips     ConocoPhillips
Company
     ConocoPhillips
Canada
Funding
Company I
    All Other
Subsidiaries
     Consolidating
Adjustments
    Total
Consolidated
 

Assets

              

Cash and cash equivalents

   $       226        35       6,650              6,911  

Short-term investments

                        2,696              2,696  

Accounts and notes receivable

     19       1,738        35       3,952        (2,380     3,364  

Investment in Cenovus Energy

           2,084                           2,084  

Inventories

           138              885              1,023  

Prepaid expenses and other current assets

     1       128        6       771        (30     876  

 

 

Total Current Assets

     20       4,314        76       14,954        (2,410     16,954  

Investments, loans and long-term receivables*

     31,001       52,867        2,493       18,571        (94,775     10,157  

Net properties, plants and equipment

           4,391              42,759        (481     46,669  

Other assets

     34       2,140        188       1,288        (2,569     1,081  

 

 

Total Assets

   $ 31,055       63,712        2,757       77,572        (100,235     74,861  

 

 

Liabilities and Stockholders’ Equity

              

Accounts payable

   $       2,480        2       3,314        (2,380     3,416  

Short-term debt

     (5     1,263        7       78        (12     1,331  

Accrued income and other taxes

           107              898              1,005  

Employee benefit obligations

           379              149              528  

Other accruals

     57       255        55       514        (30     851  

 

 

Total Current Liabilities

     52       4,484        64       4,953        (2,422     7,131  

Long-term debt

     3,785       11,816        1,705       2,845        (478     19,673  

Asset retirement obligations and accrued environmental costs

           490              7,273              7,763  

Deferred income taxes

                        8,267        (2,005     6,262  

Employee benefit obligations

           1,278              625              1,903  

Other liabilities and deferred credits*

     3,280       8,769        893       14,962        (26,487     1,417  

 

 

Total Liabilities

     7,117       26,837        2,662       38,925        (31,392     44,149  

Retained earnings

     21,607       11,914        (682     9,193        (13,902     28,130  

Other common stockholders’ equity

     2,331       24,961        777       29,242        (54,941     2,370  

Noncontrolling interests

                        212              212  

 

 

Total Liabilities and Stockholders’ Equity

   $ 31,055       63,712        2,757       77,572        (100,235     74,861  

 

 

*Includes intercompany loans.

              
Balance Sheet    December 31, 2016  

Assets

              

Cash and cash equivalents

   $       358        13       3,239              3,610  

Short-term investments

                        50              50  

Accounts and notes receivable

     22       1,968        23       6,103        (4,702     3,414  

Inventories

           84              934              1,018  

Prepaid expenses and other current assets

     2       116        8       415        (24     517  

 

 

Total Current Assets

     24       2,526        44       10,741        (4,726     8,609  

Investments, loans and long-term receivables*

     37,901       64,434        2,296       31,643        (114,602     21,672  

Net properties, plants and equipment

           6,301              52,030              58,331  

Other assets

     40       2,194        220       1,240        (2,534     1,160  

 

 

Total Assets

   $ 37,965       75,455        2,560       95,654        (121,862     89,772  

 

 

Liabilities and Stockholders’ Equity

              

Accounts payable

   $       4,683        1       3,671        (4,702     3,653  

Short-term debt

     (10     999        6       94              1,089  

Accrued income and other taxes

           85              399              484  

Employee benefit obligations

           489              200              689  

Other accruals

     171       271        40       536        (24     994  

 

 

Total Current Liabilities

     161       6,527        47       4,900        (4,726     6,909  

Long-term debt

     8,975       12,635        1,710       2,866              26,186  

Asset retirement obligations and accrued environmental costs

           925              7,500              8,425  

Deferred income taxes

                        10,972        (2,023     8,949  

Employee benefit obligations

           1,901              651              2,552  

Other liabilities and deferred credits*

     417       10,391        748       17,832        (27,863     1,525  

 

 

Total Liabilities

     9,553       32,379        2,505       44,721        (34,612     54,546  

Retained earnings

     25,025       14,015        (541     12,883        (19,834     31,548  

Other common stockholders’ equity

     3,387       29,061        596       37,798        (67,416     3,426  

Noncontrolling interests

                        252              252  

 

 

Total Liabilities and Stockholders’ Equity

   $ 37,965       75,455        2,560       95,654        (121,862     89,772  

 

 

*Includes intercompany loans.

              

 

32


Table of Contents
                                                                                         
     Millions of Dollars  
     Nine Months Ended September 30, 2017  
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

   $ (161     634       22       6,868       (2,767     4,596  

 

 

Cash Flows From Investing Activities

            

Capital expenditures and investments

           (1,230           (2,711     867       (3,074

Working capital changes associated with investing activities

           36             (54           (18

Proceeds from asset dispositions

     5,000       10,974             12,737       (14,971     13,740  

Purchases of short-term investments