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Forma (Unaudited) (Details)
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63: R53 Derivative and Financial Instruments - Schedule of HTML 37K
Income Statement Location and Gain (Loss) Amounts
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Net Exposures from Outstanding Commodity
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Net Carrying Amount of Held to Maturity
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Debt Securities Carried at Fair Value (Details)
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Amortized Cost Basis and Fair Value of Investments
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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. iYes☒ No ☐
Indicate by check mark whether the registrant
has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). iYes☒ 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.
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 ☐iNo☒
Adjustments
to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization
i3,633
i3,753
Impairments
i4
(i1)
Dry
hole costs and leasehold impairments
i104
i7
Accretion
on discounted liabilities
i122
i125
Deferred
taxes
i868
i567
Undistributed
equity earnings
i591
i317
Gain
on dispositions
(i1,079)
(i292)
Gain
on investment in Cenovus Energy
(i251)
(i726)
Other
(i37)
(i688)
Working
capital adjustments
Increase in accounts and notes receivable
(i1,861)
(i794)
Increase
in inventories
(i53)
(i89)
Increase
in prepaid expenses and other current assets
(i283)
(i388)
Increase
in accounts payable
i635
i323
Increase
(decrease) in taxes and other accruals
(i315)
i1,144
Net
Cash Provided by Operating Activities
i12,982
i6,331
Cash
Flows From Investing Activities
Capital expenditures and investments
(i5,129)
(i2,465)
Working
capital changes associated with investing activities
i496
i2
Acquisition
of businesses, net of cash acquired
i37
i382
Proceeds
from asset dispositions
i2,951
i160
Net
(purchase) sale of investments
(i1,104)
i1,302
Collection
of advances/loans—related parties
i55
i52
Other
(i8)
i86
Net
Cash Used in Investing Activities
(i2,702)
(i481)
Cash
Flows From Financing Activities
Issuance of debt
i2,897
i—
Repayment
of debt
(i5,829)
(i44)
Issuance
of company common stock
i350
(i25)
Repurchase
of company common stock
(i3,725)
(i981)
Dividends
paid
(i1,852)
(i1,171)
Other
(i56)
i3
Net
Cash Used in Financing Activities
(i8,215)
(i2,218)
Effect
of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash
(i237)
i9
Net
Change in Cash, Cash Equivalents and Restricted Cash
i1,828
i3,641
Cash,
cash equivalents and restricted cash at beginning of period
i5,398
i3,315
Cash,
Cash Equivalents and Restricted Cash at End of Period
$
i7,226
i6,956
Restricted
cash of $i317 million is included in the "Other assets" line of our Consolidated Balance Sheet as of June 30, 2022.
Restricted cash of $i152 million
and $i218 million are included in the "Prepaid expenses and other current assets" and "Other assets" lines, respectively, of our Consolidated Balance Sheet as of December 31, 2021.
iThe 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, 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 2021 Annual Report on Form 10-K.
/
i
Note 2—Inventories
i
Millions
of Dollars
June 30 2022
December 31 2021
Crude oil and natural gas
$
i653
i647
Materials
and supplies
i581
i561
Total
Inventories
$
i1,234
i1,208
Inventories
valued on the LIFO basis
$
i326
i395
/
/
i
Note
3—Acquisitions and Dispositions
Acquisition of Shell Enterprise LLC's (Shell) Permian Assets
In December 2021, we completed our acquisition of Shell's assets in the Permian based Delaware Basin in an all-cash transaction for $i8.6 billion after customary adjustments. Assets acquired include approximately i225,000
net acres and producing properties located entirely in Texas. The acquisition was accounted for as a business combination under FASB Topic ASC 805 using the acquisition method, which requires assets acquired and liabilities assumed to be measured at their acquisition date fair values. Fair value measurements were made for acquired assets and liabilities, and adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date as we identify new information about facts and circumstances that existed as of the acquisition date to consider.
Oil and gas properties were valued using a discounted cash flow approach incorporating market participant and internally generated price assumptions, production profiles, and operating and development cost assumptions. The fair values determined for accounts receivable, accounts payable, and most other current assets and current liabilities
were equivalent to the carrying value due to their short-term nature. The total consideration of $i8.6 billion was allocated to the identifiable assets and liabilities based on their fair values at the acquisition date.
Asset
retirement obligations and accrued environmental costs
i86
Other liabilities and deferred credits
i36
Total
liabilities assumed
$
i354
Net assets acquired
$
i8,635
/
With
the completion of the Shell Permian transaction, we acquired proved and unproved properties of approximately $i4.2 billion and $i4.3 billion, respectively.
Supplemental
Pro Forma (unaudited)
i
The following table summarizes the unaudited supplemental pro forma financial information for the three- and six-month periods ended June 30, 2021, as if we had completed the acquisition of Shell's Permian assets on January 1, 2020:
The
unaudited supplemental pro forma financial information is presented for illustration and comparative purposes only and is not necessarily indicative of the operating results that would have occurred had the transaction been completed on January 1, 2020, nor is it necessarily indicative of future operating results of the combined entity. The unaudited pro forma financial information for the three- and six-month periods ended June 30, 2021, is a result of combining the consolidated income statement of ConocoPhillips with the results of the assets acquired from Shell. The pro forma results do not include transaction-related costs, nor any cost savings anticipated as a result of the transaction. The pro forma results include adjustments made primarily to DD&A, which is based on the unit-of-production method, resulting from the purchase price allocated to properties, plants
and equipment. We believe the estimates and assumptions are reasonable, and the relative effects of the transaction are properly reflected.
In January 2021, we completed our acquisition of Concho, an independent oil and gas exploration and production company in an all-stock transaction. In conjunction with this acquisition, we commenced, and completed in 2021, a company-wide restructuring program, the scope of which included combining the operations of the two companies as well as other global restructuring activities for which we recognized non-recurring restructuring and transaction costs. Further information regarding the Concho acquisition can be found in the following footnotes: Note 7—Changes
in Equity; Note 9—Contingencies and Commitments; Note 10—Derivative and Financial Instruments; and Note 13—Cash
Flow Informationand should be read in conjunction with the notes included in our Annual Report on Form 10-K.
Acquisition of Additional Shareholding Interest in Australia Pacific LNG Pty Ltd (APLNG)
In February 2022, we completed the acquisition of an additional i10 percent interest in APLNG from Origin Energy for approximately $i1.4
billion, after customary adjustments, in an all-cash transaction resulting from the exercise of our preemption right. This increases our ownership in APLNG to i47.5 percent, with Origin Energy and Sinopec owning
i27.5
percent and i25 percent, respectively. APLNG is reported as an equity investment in our Asia Pacific segment.
Assets Sold
In April 2022, we sold our interests in certain noncore assets in the Lower 48 segment for net proceeds of $i370
million and recognized a $i80 million before-tax and $i63
million after-tax gain. At the time of disposition, our interests in these assets had a net carrying value of $i290 million, consisting primarily of $i401
million of PP&E and $i111 million of liabilities, primarily related to AROs.
In March 2022, we completed the divestiture of our subsidiaries that held our Indonesia assets and operations, and based on an effective date of January 1, 2021, we received net proceeds of $i731
million after customary adjustments and recognized a $i534 million before-tax and $i462 million
after-tax gain related to this transaction. Together, the subsidiaries sold indirectly held our i54 percent interest in the Indonesia Corridor Block Production Sharing Contract (PSC) and
i35
percent shareholding in the Transasia Pipeline Company. At the time of the disposition, the net carrying value was approximately $i0.2 billion, excluding $i0.2
billion of cash and restricted cash. The net book value consisted primarily of $i0.3 billion of PP&E and $i0.1
billion of ARO. The before-tax earnings associated with the subsidiaries sold, excluding the gain on disposition noted above, were $i138 million and $i264
million for the six-month period ended June 30, 2022 and 2021, respectively. Results of operations for the Indonesia interests sold were reported in our Asia Pacific segment.
For the three- and six-months ended June 30, 2022, we recorded contingent payments of $i174 million and $i424
million, respectively, relating to the previous dispositions of our interest in the Foster Creek Christina Lake Partnership and western Canada gas assets as well as our San Juan assets. The contingent payments are recorded as gain on disposition in our consolidated income statement and are reflected within our Canada and Lower 48 segments. For the three- and six-months ended June 30, 2021, we recorded contingent payments of $i68 million and $i94
million, respectively.
Planned Dispositions
In July 2022, we entered into agreements to sell our interests in certain noncore assets in the Lower 48 segment for $i265 million, before customary adjustments. These transactions are expected to close in the third quarter of 2022.
Note
4—Investments, Loans and Long-Term Receivables
APLNG
APLNG executed project agreements for an $i8.5 billion project finance facility in 2012 which became non-recourse following financial completion in 2017. Following restructuring efforts, the facility is currently composed of a financing agreement with the Export-Import Bank of the United States, a commercial bank facility and two United States Private Placement note facilities. APLNG principal and interest
payments commenced in March 2017 and are scheduled to occur bi-annually until September 2030. At June 30, 2022, a balance of $i5.5 billion was outstanding on these facilities.
In February 2022, we completed the acquisition
of an additional i10 percent interest in APLNG from Origin Energy for approximately $i1.4
billion resulting from the exercise of our preemption right. This increases our ownership in APLNG to i47.5 percent, with Origin Energy and Sinopec owning i27.5
percent and i25 percent, respectively.
At June 30, 2022, the carrying value of our equity method investment in APLNG was $i6.4
billion. The balance is included in the “Investments and long-term receivables” line on our consolidated balance sheet.
Loans
As part of our normal ongoing business operations, we enter into numerous agreements with other parties to pursue business opportunities. Included in such activity are loans made to certain affiliated and non-affiliated companies. At June 30, 2022, significant loans to affiliated companies included $i59 million in project financing
to Qatar Liquefied Gas Company Limited (3), which is included within the “Accounts and notes receivable—related parties” line on our consolidated balance sheet.
/
i
Note 5—Investment in
Cenovus Energy
At December 31, 2021, we held i91 million common shares of Cenovus Energy (CVE), which approximated i4.5%
of their issued and outstanding common shares. Those shares were carried on our balance sheet at fair value of $i1.1 billion based on NYSE closing price of $i12.28 per share on the last day of trading for the period. During the first
quarter of 2022, we sold our remaining i91 million shares, recognizing proceeds of $i1.4 billion.
All
gains and losses were recognized within "Other income” on our consolidated income statement. Proceeds related to the sale of our CVE shares were included within “Cash Flows from Investing Activities” on our consolidated statement of cash flows. See Note 11.
i
Millions
of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
2022
2021
2022
2021
Total Net gain on equity securities
$
i—
i418
i251
i726
Less:
Net gain on equity securities sold during the period
i—
i31
i251
i60
Unrealized
gain on equity securities still held at the reporting date
In May 2022, we redeemed $i1,250 million
principal amount of our i4.95 percent Notes due 2026. We paid premiums above face value of $i79 million
to redeem the debt and recognized a loss on debt extinguishment of $i83 million which is included in the "Other expenses" line on our consolidated income statement. We also paid $i500 million
to retire the outstanding principal amount of the floating rate notes due 2022 at maturity.
In the first quarter of 2022, we completed a debt refinancing consisting of three concurrent transactions: a tender offer to repurchase existing debt for cash; exchange offers to retire certain debt in exchange for new debt and cash; and a new debt issuance to partially fund the cash paid in the tender and exchange offers.
Tender Offer
In March 2022, we repurchased a total of $i2,716
million aggregate principal amount of debt as listed below. We paid premiums above face value of $i333 million to repurchase these debt instruments and recognized a gain on debt extinguishment of $i155
million which is included in the "Other expenses" line on our consolidated income statement.
•i3.75% Notes due 2027 with principal of $i1,000
million (partial repurchase of $i804 million)
•i4.3% Notes due 2028 with principal of $i1,000
million (partial repurchase of $i777 million)
•i2.4% Notes due 2031 with principal of $i500
million (partial repurchase of $i273 million)
•i4.875% Notes due 2047 with principal of $i800
million (partial repurchase of $i481 million)
•i4.85% Notes due 2048 with principal of $i600
million (partial repurchase of $i381 million)
Exchange Offers
Also in March 2022, we completed itwo
concurrent debt exchange offers through which $i2,544 million of aggregate principal of existing notes was tendered and accepted in exchange for a combination of new notes and cash. The debt exchange offers were treated as debt modifications for accounting purposes resulting in a portion of the unamortized debt discount, premiums and debt issuance costs of the existing notes being allocated to the new notes on the settlement dates of the exchange offers. We paid premiums above face value of $i883
million, comprised of $i872 million of cash as well as new notes, which were capitalized as additional debt discount. We incurred expenses of $i28 million in the exchanges
which are included in the "Other expenses" line on our consolidated income statement.
The notes tendered and accepted in the exchange offers were:
•i7% Debentures due 2029 with principal amount of $i200
million (partial exchange of $i88 million)
•i6.95% Notes due 2029 with principal amount of $i1,549
million (partial exchange of $i354 million)
•i7.4% Notes due 2031 with principal amount of $i500
million (partial exchange of $i118 million)
•i7.25% Notes due 2031 with principal amount of $i500
million (partial exchange of $i100 million)
•i7.2% Notes due 2031 with principal amount of $i575
million (partial exchange of $i128 million)
•i5.95% Notes due 2036 with principal amount of $i500
million (partial exchange of $i174 million)
•i5.9% Notes due 2038 with principal amount of $i600
million (partial exchange of $i250 million)
•i6.5% Notes due 2039 with principal amount of $i2,750 million
(partial exchange of $i1,162 million)
•i5.95% Notes due 2046 with principal amount of $i500
million (partial exchange of $i171 million)
The notes tendered and accepted were exchanged for the following new notes:
•i3.758%
Notes due 2042 with principal amount of $i785 million
•i4.025% Notes due 2062 with principal amount of $i1,770
million
New Debt Issuance
On March 8, 2022, we issued the following new notes consisting of:
•i2.125% Notes due 2024 with principal of $i900
million
•i2.4% Notes due 2025 with principal of $i900 million
•i3.8%
Notes due 2052 with principal of $i1,100 million
In February 2022, we refinanced our revolving credit facility from a total borrowing capacity of $i6.0 billion
to $i5.5 billion with an expiration date of February 2027. Our revolving credit facility may be used for direct bank borrowings, the issuance of letters of credit totaling up to $i500
million, or as support for our commercial paper program. The revolving credit facility is broadly syndicated among financial institutions and does not contain any material adverse change provisions or any covenants requiring maintenance of specified financial ratios or credit ratings. The facility agreement contains a cross-default provision relating to the failure to pay principal or interest on other debt obligations of
$i200 million or more by ConocoPhillips, or any of its consolidated subsidiaries.
The amount of the facility is not subject to redetermination prior to its expiration date.
Credit facility borrowings may bear interest at a margin above rates offered by certain designated banks in the London interbank market or at a margin above the overnight federal funds rate or prime rates offered by certain designated banks in the U.S. The facility agreement calls for commitment fees on available, but unused, amounts. The facility agreement also contains early termination rights if our current directors or their approved successors cease to be a majority of the Board of Directors.
The revolving credit facility supports our ability to issue up to $i5.5
billion of commercial paper. Commercial paper is generally limited to maturities of 90 days and is included in short-term debt on our consolidated balance sheet. With ino commercial paper outstanding and ino
direct borrowings or letters of credit, we had access to $i5.5 billion in available borrowing capacity under our revolving credit facility at June 30, 2022. At December 31, 2021, we had ino
commercial paper outstanding and ino direct borrowings or letters of credit issued.
The current credit ratings on our long-term debt are:
•Fitch: “A” with a “stable” outlook
•S&P: “A-” with a “stable” outlook
•Moody’s: “A3” with a “positive” outlook
We
do not have any ratings triggers on any of our corporate debt that would cause an automatic default, and thereby impact our access to liquidity upon downgrade of our credit ratings. If our credit ratings are downgraded from their current levels, it could increase the cost of corporate debt available to us and restrict our access to the commercial paper markets. If our credit ratings were to deteriorate to a level prohibiting us from accessing the commercial paper market, we would still be able to access funds under our revolving credit facility.
At June 30, 2022, we had $i283
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. If they are ever redeemed, we have the ability and intent to refinance on a long-term basis, therefore, the VRDBs are included in the “Long-term debt” line on our consolidated balance sheet.
At June 30, 2022, we were liable for certain contingent obligations under various contractual arrangements as described below. We recognize a liability, at inception, for the fair value of our obligation as a guarantor for newly issued or modified guarantees. Unless the carrying amount of the liability is noted below, we have not recognized a liability because the fair value of the obligation is immaterial. In addition, unless otherwise stated, we are not currently performing with any significance under the guarantee and expect future performance to be either immaterial or have only a remote chance of occurrence.
APLNG Guarantees
At June 30, 2022, we had outstanding multiple guarantees in connection with our i47.5
percent ownership interest in APLNG. The following is a description of the guarantees with values calculated utilizing June 2022 exchange rates:
•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 i9 years. Our maximum exposure under this guarantee is approximately $i210
million and may become payable if an enforcement action is commenced by the project finance lenders against APLNG. At June 30, 2022, the carrying value of this guarantee was $i14 million.
•In conjunction with our original purchase of an ownership interest in APLNG from Origin Energy Limited in October 2008, we agreed to reimburse Origin Energy Limited 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. The final guarantee expires in the fourth quarter of 2041. Our maximum potential liability for future payments, or cost of volume delivery, under these guarantees is estimated to be $i820 million ($i1.4
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-ventures 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 i15
to i23 years or the life of the venture. Our maximum potential amount of future payments related to these guarantees is approximately $i290 million and would become payable if APLNG does not perform. At June 30,
2022, the carrying value of these guarantees was approximately $i20 million.
Other Guarantees
We have other guarantees with maximum future potential payment amounts totaling approximately $i720
million, which consist primarily of guarantees of the residual value of leased office buildings, guarantees of the residual value of corporate aircrafts, and a guarantee for our portion of a joint venture’s project finance reserve accounts. These guarantees have remaining terms of one to ifive years and would become payable if certain asset values are lower than guaranteed amounts at the end of the lease or contract term, business conditions decline at guaranteed entities, or as a result of nonperformance of contractual terms by
guaranteed parties. At June 30, 2022, the carrying value of these guarantees was $i8 million.
Indemnifications
Over the years, we have entered into agreements to sell ownership interests in certain legal entities, joint ventures and assets that gave rise to qualifying indemnifications. These agreements include indemnifications for taxes and environmental liabilities. The carrying amount recorded for these indemnification
obligations at June 30, 2022, was
$i20 million. Those related to environmental issues have terms that are generally indefinite and the maximum amounts of future payments are generally unlimited. 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. See
Note 9for additional information about environmental liabilities.
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 and no amount within the range is a better estimate than any other amount, then the low end of the range is accrued. We do not reduce these liabilities for potential insurance or third-party recoveries. We accrue receivables for insurance or other third-party recoveries when applicable. 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 such factors 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 and record accruals for environmental liabilities based on management’s best estimates. These estimates are based 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. EPA or other organizations. We consider unasserted claims in our determination of environmental liabilities, and we accrue them in the period they are both probable and reasonably estimable.
Although liability of those potentially responsible for environmental
remediation costs is generally joint and several for federal sites and frequently so for other sites, we are usually only one of many companies cited at a particular site. Due to the joint and several liabilities, we could be responsible for all cleanup costs related to any site at which we have been designated as a potentially responsible party. We have been successful to date in sharing cleanup costs with other financially sound companies. Many of the sites at which we are potentially responsible are still under investigation by the EPA or the agency concerned. Prior to actual cleanup, those potentially responsible normally assess the site conditions, apportion responsibility and determine the appropriate remediation. In some instances, we may have no liability or may attain a settlement of liability. Where it appears that other potentially responsible parties may be financially unable to bear their proportional share, we consider this inability in estimating our potential
liability, and we adjust our accruals accordingly. As a result of various acquisitions in the past, we assumed certain environmental obligations. Some of these environmental obligations are mitigated by indemnifications made by others for our benefit, and some of the indemnifications are subject to dollar limits and time limits.
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. We have not reduced these accruals for possible insurance recoveries.
At
June 30, 2022, our balance sheet included a total environmental accrual of $i178 million, compared with $i187
million at December 31, 2021, for remediation activities in the U.S. and Canada. We expect to incur a substantial amount of these expenditures within the next i30 years. In the future, we may be involved in additional environmental assessments, cleanups and 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, climate change, 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, claims of alleged environmental contamination and damages from historic operations, and climate change. 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.
We have contingent liabilities resulting from throughput agreements with pipeline and processing companies not associated with financing arrangements. Under these agreements, we may be required to provide any such company with additional funds through advances and penalties for fees related to throughput capacity not utilized. In addition, at June 30, 2022, we had performance obligations secured by letters of credit of $i320
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, ConocoPhillips was unable to reach agreement with respect to the 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, ConocoPhillips initiated international arbitration on November 2, 2007, with the ICSID. 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. In March 2019, the Tribunal unanimously ordered the government of Venezuela to pay ConocoPhillips approximately $i8.7 billion in compensation for the government’s unlawful expropriation of the company’s investments in Venezuela in 2007. On August 29,
2019, the ICSID Tribunal issued a decision rectifying the award and reducing it by approximately $i227 million. The award now stands at $i8.5
billion plus interest. The government of Venezuela sought annulment of the award, which automatically stayed enforcement of the award. On September 29, 2021, the ICSID annulment committee lifted the stay of enforcement of the award.
In 2014, ConocoPhillips filed a separate and independent arbitration under the rules of the ICC against PDVSA under the contracts that had established the Petrozuata and Hamaca projects. The ICC Tribunal issued an award in April 2018, finding that PDVSA owed ConocoPhillips approximately $i2
billion under their agreements in connection with the expropriation of the projects and other pre-expropriation fiscal measures. In August 2018, ConocoPhillips entered into a settlement with PDVSA to recover the full amount of this ICC award, plus interest through the payment period, including initial payments totaling approximately $i500 million within a period of 90 days from the time of signing of the settlement agreement. The balance of the settlement is to be paid quarterly over a period of four and a half years.
Per the settlement, PDVSA recognized the ICC award as a judgment in various jurisdictions, and ConocoPhillips agreed to suspend its legal enforcement actions. ConocoPhillips sent notices of default to PDVSA on October 14 and November 12, 2019, and to date PDVSA has failed to cure its breach. As a result, ConocoPhillips has resumed legal enforcement actions. To date, ConocoPhillips has received approximately $i771 million in connection with the ICC award. ConocoPhillips has ensured that the settlement and any actions
taken in enforcement thereof meet all appropriate U.S. regulatory requirements, including those related to any applicable sanctions imposed by the U.S. against Venezuela.
In 2016, ConocoPhillips filed a separate and independent arbitration under the rules of the ICC against PDVSA under the contracts that had established the Corocoro Project. On August 2, 2019, the ICC Tribunal awarded ConocoPhillips approximately $i33
million plus interest under the Corocoro contracts. ConocoPhillips is seeking recognition and enforcement of the award in various jurisdictions. ConocoPhillips has ensured that all the actions related to the award meet all appropriate U.S. regulatory requirements, including those related to any applicable sanctions imposed by the U.S. against Venezuela.
Beginning in 2017, governmental and other entities in several states in the U.S. have filed lawsuits against oil and gas companies, including ConocoPhillips, seeking compensatory damages and equitable relief to abate alleged climate change impacts. Additional lawsuits with similar allegations are expected to be filed. The amounts claimed by plaintiffs are unspecified and the legal and factual issues are unprecedented, therefore, there is significant uncertainty about the scope of the claims and alleged damages and any potential impact on the Company’s financial condition. ConocoPhillips believes these
lawsuits are factually and legally meritless and are an inappropriate vehicle to address the challenges associated with climate change and will vigorously defend against such lawsuits.
Several Louisiana parishes and the State of Louisiana have filed i43 lawsuits under Louisiana’s State and Local Coastal Resources Management Act (SLCRMA) against oil and gas companies, including ConocoPhillips, seeking compensatory damages for contamination and erosion of the Louisiana coastline allegedly caused by historical oil and gas operations. ConocoPhillips
entities are defendants in i22 of the lawsuits and will vigorously defend against them. Because Plaintiffs’ SLCRMA theories are unprecedented, there is uncertainty about these claims (both as to scope and damages) and we continue to evaluate our exposure in these lawsuits.
In October 2020, the Bureau of Safety and Environmental Enforcement (BSEE) ordered the prior owners of Outer Continental Shelf (OCS) Lease P-0166, including ConocoPhillips, to decommission the lease facilities, including two offshore platforms located near Carpinteria,
California. This order was sent after the current owner of OCS Lease P-0166 relinquished the lease and abandoned the lease platforms and facilities. BSEE’s order to ConocoPhillips is premised on its connection to Phillips Petroleum Company, a legacy company of ConocoPhillips, which held a historical i25 percent interest in this lease and operated these facilities but sold its interest approximately i30
years ago. ConocoPhillips is challenging the BSEE order but continues to evaluate its exposure in this matter.
On May 10, 2021, ConocoPhillips filed arbitration under the rules of the Singapore International Arbitration Centre (SIAC) against Santos KOTN Pty Ltd. and Santos Limited for their failure to timely pay the $i200 million bonus due upon final investment decision of the Barossa development project under the sale and purchase agreement. Santos KOTN Pty
Ltd. and Santos Limited have filed a response and counterclaim, and the arbitration is underway.
In July 2021, a federal securities class action was filed against Concho, certain of Concho’s officers, and ConocoPhillips as Concho’s successor in the United States District Court for the Southern District of Texas. On October 21, 2021, the court issued an order appointing Utah Retirement Systems and the Construction Laborers Pension Trust for Southern California as lead plaintiffs (Lead Plaintiffs). On January 7, 2022, the Lead Plaintiffs filed their consolidated complaint alleging that Concho made materially false and misleading statements regarding its business and operations in violation of the federal securities laws and seeking unspecified damages, attorneys’ fees, costs, equitable/injunctive relief, and such other relief that
may be deemed appropriate. We believe the allegations in the action are without merit and are vigorously defending this litigation.
i
Note 10—Derivative and Financial Instruments
We use futures, forwards, swaps and options in various markets to meet our customer needs, capture market opportunities and manage
foreign exchange currency risk.
Commodity Derivative Instruments
Our commodity business primarily consists of natural gas, crude oil, bitumen, LNG and NGLs.
Commodity 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, 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 NPNS exception are recognized upon settlement. We generally apply this exception to eligible crude contracts and certain gas contracts. We do not apply hedge accounting for our commodity derivatives.
The following table presents the gross fair values of our commodity derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet:
Millions
of Dollars
June 30 2022
December 31 2021
Assets
Prepaid expenses and other current assets
$
i1,790
i1,168
Other
assets
i262
i75
Liabilities
Other
accruals
i1,824
i1,160
Other
liabilities and deferred credits
i232
i63
/i
The
gains (losses) from commodity derivatives incurred and the line items where they appear on our consolidated income statement were:
Millions of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
2022
2021
2022
2021
Sales
and other operating revenues
$
(i13)
(i100)
(i420)
(i379)
Other
income
i1
(i1)
i2
i16
Purchased
commodities
(i55)
i132
i346
i145
/
During
the first quarter of 2021, we recognized a $i305 million loss on settlement of derivative contracts acquired through the Concho transaction. This loss is recorded within the “Sales and other operating revenues” line on our consolidated income statement. In connection with this settlement, we issued a cash payment of $i692
million in the first quarter of 2021 and $i69 million in the second quarter of 2021 which are included within “Cash Flows From Operating Activities” on our consolidated statement of cash flows.
i
The
table below summarizes our material net exposures resulting from outstanding commodity derivative contracts:
Open Position Long (Short)
June 30 2022
December 31 2021
Commodity
Natural gas and power (billions of cubic feet equivalent)
We invest in financial instruments with maturities based on our cash forecasts for the various accounts and currency pools we manage. The types of
financial instruments in which we currently invest include:
•Time deposits: Interest bearing deposits placed with financial institutions for a predetermined amount of time.
•Demand deposits: Interest bearing deposits placed with financial institutions. Deposited funds can be withdrawn without notice.
•Commercial paper: Unsecured promissory notes issued by a corporation, commercial bank or government agency purchased at a discount to mature at par.
•U.S. government or government agency obligations: Securities issued by the U.S. government or U.S. government agencies.
•Foreign government obligations: Securities issued by foreign governments.
•Corporate
bonds: Unsecured debt securities issued by corporations.
The following investments are carried on our consolidated balance sheet at cost, plus accrued interest, and the table reflects remaining maturities at June 30, 2022, and December 31, 2021:
The
following investments in debt securities classified as available for sale are carried at fair value on our consolidated balance sheet at June 30, 2022 and December 31, 2021:
Millions of Dollars
Carrying Amount
Cash
and Cash Equivalents
Short-Term Investments
Investments and Long-Term Receivables
June 30 2022
December 31 2021
June 30 2022
December 31 2021
June 30 2022
December 31 2021
Major Security Type
Corporate
Bonds
$
i—
i3
i299
i128
i298
i173
Commercial
Paper
i120
i7
i215
i82
U.S.
Government Obligations
i—
i—
i68
i—
i94
i2
U.S.
Government Agency Obligations
i5
i2
i5
i8
Foreign
Government Obligations
i2
i7
i4
i2
Asset-backed
Securities
i—
i2
i100
i63
$
i120
i10
i589
i221
i501
i248
/
Cash
and Cash Equivalents and Short-Term Investments have remaining maturities within one year.
Investments and Long-Term Receivables have remaining maturities greater than ione year through iseven
years.
The following table summarizes the amortized cost basis and fair value of investments in debt securities classified as available for sale:
Millions of Dollars
Amortized Cost Basis
Fair Value
June 30 2022
December
31 2021
June 30 2022
December 31 2021
Major Security Type
Corporate Bonds
$
i604
i305
i597
i304
Commercial
Paper
i335
i88
i335
i89
U.S.
Government Obligations
i163
i2
i162
i2
U.S.
Government Agency Obligations
i10
i10
i10
i10
Foreign
Government Obligations
i6
i9
i6
i9
Asset-backed
Securities
i100
i65
i100
i65
$
i1,218
i479
i1,210
i479
As
of June 30, 2022 and December 31, 2021, total unrealized losses for debt securities classified as available for sale with net losses were negligible. Additionally, as of June 30, 2022 and December 31, 2021, investments in these debt securities in an unrealized loss position for which an allowance for credit losses has not been recorded were negligible.
For the three- and six-month periods ended June 30, 2022, proceeds from sales and redemptions of investments in debt securities classified as available for sale were $i86
million and $i201 million, respectively. For the three- and six-month periods ended June 30, 2021, proceeds from sales and redemptions of investments in debt securities classified as available for sale were $i173
million and $i320 million, respectively. Gross realized gains and losses included in earnings from those sales and redemptions were negligible. The cost of securities sold and redeemed is determined using the specific identification method.
Financial instruments potentially exposed to concentrations of credit risk consist primarily of cash equivalents, short-term investments, long-term investments in debt securities, OTC derivative contracts
and trade receivables. Our cash equivalents and short-term investments are placed in high-quality commercial paper, government money market funds, U.S. government and government agency obligations, time deposits with major international banks and financial institutions, high-quality corporate bonds, foreign government obligations and asset-backed securities. Our long-term investments in debt securities are placed in high-quality corporate bonds, asset-backed securities, U.S. government and government agency obligations, and foreign government obligations.
The credit risk from our OTC derivative contracts, such as forwards, swaps and options, 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 primarily 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 oil and gas 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 i30
days or less, and we continually monitor this exposure and the creditworthiness of the counterparties. We may require collateral to limit the exposure to loss including letters of credit, prepayments and surety bonds, as well as 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 at June 30, 2022 and December 31, 2021 was $i326
million and $i281 million, respectively. For these instruments, collateral posted at June 30, 2022 was $i6
million and ino collateral was posted at December 31, 2021. If our credit rating had been downgraded below investment grade at June 30, 2022, we would have been required to post
$i238
million of additional collateral, either with cash or letters of credit.
i
Note 11—Fair Value Measurement
We carry a portion of our assets and liabilities at fair value that are measured at the 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 fair value hierarchy.
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. There were no material transfers into or out of Level 3 during the six-month period ended June 30, 2022, nor during the year ended December 31, 2021.
Financial assets and liabilities reported at fair value on a recurring basis includes our investment in CVE common shares, our investments in debt securities classified as available for
sale, and 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 1 also includes our investment in common shares of CVE, which is valued using quotes for shares on the NYSE, and our investments in U.S. government obligations classified as available for sale debt securities, which are valued using exchange prices.
•Level 2 derivative assets and liabilities primarily represent OTC swaps, options and forward purchase and sale contracts that are valued using adjusted exchange prices, prices provided by brokers or pricing service companies that are all corroborated by market data. Level 2 also includes
our investments in debt securities classified as available for sale including investments in corporate bonds, commercial paper, asset-backed securities, U.S. government agency obligations and foreign government obligations that are valued using pricing provided by brokers or pricing service companies that are corroborated with market data.
•Level 3 derivative assets and liabilities consist of OTC swaps, options and forward purchase and sale contracts where a significant portion of fair value is calculated from underlying market data that is not readily available. The derived value uses industry standard methodologies that may consider the historical relationships among various commodities, modeled market prices, time value, volatility factors and other relevant economic measures. The use of these inputs results
in management’s best estimate of fair value. Level 3 activity was not material for all periods presented.
i
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):
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.
At
June 30, 2022 and December 31, 2021, we did not present any amounts gross on our consolidated balance sheet where we had the right of setoff.
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. For those investments classified as available for sale debt securities, the carrying amount reported on the balance sheet is 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.
•Investment in Cenovus Energy: See Note 5 for a discussion of the carrying value and fair value of our investment in CVE common shares.
•Investments in debt securities classified as available for sale: The fair value of investments in debt securities categorized as Level 1 in the fair value hierarchy is measured using exchange prices. The fair value of investments in debt securities
categorized as Level 2 in the fair value hierarchy is measured using pricing provided by brokers or pricing service companies that are corroborated with market data. See Note 10.
•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 4.
•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.
•Commercial paper: The carrying amount of our commercial paper instruments approximates fair value and is reported on the balance sheet as short-term debt.
The following
table summarizes the net fair value of financial instruments (i.e., adjusted where the right of setoff exists for commodity derivatives):
Millions of Dollars
Carrying Amount
Fair Value
June
30 2022
December 31 2021
June 30 2022
December 31 2021
Financial assets
Investment in CVE common shares
$
i—
i1,117
i—
i1,117
Commodity
derivatives
i750
i593
i750
i593
Investments
in debt securities
i1,210
i479
i1,210
i479
Loans
and advances—related parties
i59
i114
i59
i114
Financial
liabilities
Total debt, excluding finance leases
i15,687
i18,673
i16,547
i22,451
Commodity
derivatives
i706
i537
i706
i537
/
i
Note
12—Accumulated Other Comprehensive Loss
i
Accumulated other comprehensive loss in the equity section of our consolidated balance sheet includes:
The
following table summarizes reclassifications out of accumulated other comprehensive loss and into net income (loss):
Millions of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
2022
2021
2022
2021
Defined
benefit plans
$
i12
i42
i16
i54
The
above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of $i3 million and $i11
million for the three-month periods ended June 30, 2022 and June 30, 2021, respectively, and $i5 million and $i15
million for the six-month periods ended
In
the first quarter of 2021, we acquired Concho in an all-stock transaction for $i13.1 billion. In connection with this transaction, we acquired cash of $i382
million, which is included in "Cash Flows From Investing Activities" on our consolidated statement of cash flows.
The components of net periodic benefit cost, other than the service cost component, are included in the "Other expenses" line of our consolidated income statement.
During the first six months of 2022, we contributed $i44
million to our domestic benefit plans and $i77 million to our international benefit plans. We expect our total contributions in 2022 to be approximately $i95
million to our domestic qualified and nonqualified pension and postretirement benefit plans and $i90 million to our international qualified and nonqualified pension and postretirement benefit plans.
During the three-month period ended June 30, 2022, lump-sum benefit payments exceeded the sum of service and interest costs for the year for the U.S. qualified pension plan and a U.S. nonqualified supplemental
retirement plan. As a result, we recognized a proportionate share of prior actuarial losses from other comprehensive income as pension settlement expense of $i18 million. In conjunction with the recognition of pension settlement expense, the fair market values of the pension plan assets were updated and the pension benefit obligations of the U.S. qualified pension plan and the U.S. nonqualified supplemental retirement plan were remeasured at June 30,
2022. At the measurement date, the net pension liability increased by $i82 million, primarily a result of lower than premised return on assets, partially offset by an increase in the discount rate, resulting in a corresponding decrease to other comprehensive income.
i
The
relevant discount rates are summarized in the following table:
June 30 2022
December 31 2021
Relevant discount rates
U.S. qualified pension plan
i4.85
%
i2.85
U.S.
nonqualified pension plan
i4.70
i2.50
/
i
Note
15—Related Party Transactions
Our related parties primarily include equity method investments and certain trusts for the benefit of employees.
i
Millions
of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
Significant Transactions with Equity Affiliates
2022
2021
2022
2021
Operating revenues and other income
$
i21
i24
i43
i40
Purchases
i—
i3
i—
i3
Operating
expenses and selling, general and administrative expenses
i44
i63
i90
i89
Net
interest (income) expense*
$
i—
i—
(i1)
(i1)
*We
paid interest to, or received interest from, various affiliates. See Note 4for information related to loans to equity affiliates.
Revenues
from contracts outside the scope of ASC Topic 606 relate primarily to physical gas contracts at market prices which qualify as derivatives accounted for under ASC Topic 815, “Derivatives and Hedging,” and for which we have not elected NPNS. There is no significant difference in contractual terms or the policy for recognition of revenue from these contracts and those within the scope of ASC Topic 606. The following disaggregation of revenues is provided in conjunction with Note 17—Segment
Disclosures and Related Information:
Millions of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
2022
2021
2022
2021
Revenue
from Outside the Scope of ASC Topic 606 by Segment
Lower 48
$
i3,483
i1,345
i5,927
i3,811
Canada
i807
i207
i1,367
i510
Europe,
Middle East and North Africa
i121
i202
i257
i407
Physical
contracts meeting the definition of a derivative
$
i4,411
i1,754
i7,551
i4,728
Millions
of Dollars
Three Months Ended
June 30
Six Months Ended
June 30
2022
2021
2022
2021
Revenue from Outside the Scope of ASC Topic 606 by Product
Crude oil
$
i64
i178
i283
i302
Natural
gas
i4,254
i1,504
i7,027
i4,231
Other
i93
i72
i241
i195
Physical
contracts meeting the definition of a derivative
$
i4,411
i1,754
i7,551
i4,728
i
Practical
Expedients
Typically, our commodity sales contracts are less than 12 months in duration; however, in certain specific cases they may extend longer, which may be out to the end of field life. We have long-term commodity sales contracts which use prevailing market prices at the time of delivery, and under these contracts, the market-based variable consideration for each performance obligation (i.e., delivery of commodity) is allocated to each wholly unsatisfied performance obligation within the contract. Accordingly, we have applied the practical expedient allowed in ASC Topic
606 and do not disclose the aggregate amount of the transaction price allocated to performance obligations or when we expect to recognize revenues that are unsatisfied (or partially unsatisfied) as of the end of the reporting period.
At
June 30, 2022, the “Accounts and notes receivable” line on our consolidated balance sheet includes trade receivables of $i6,554 million compared with $i5,268
million at December 31, 2021, and includes both contracts with customers within the scope of ASC Topic 606 and those that are outside the scope of ASC Topic 606. We typically receive payment within 30 days or less (depending on the terms of the invoice) once delivery is made. Revenues that are outside the scope of ASC Topic 606 relate primarily to physical gas sales contracts at market prices for which we do not elect NPNS and are therefore accounted for as a derivative under ASC Topic 815. There is little distinction in the nature of the customer or credit quality of trade receivables associated with gas sold under contracts for which NPNS has not
been elected compared to trade receivables where NPNS has been elected.
We have entered into certain agreements under which we license our proprietary technology, including the Optimized Cascade® process technology, to customers to maximize the efficiency of LNG plants. These agreements typically provide for milestone payments to be made during and after the construction phases of the LNG plant. The payments are not directly related to our performance obligations under the contract and are recorded as deferred revenue to be recognized when the customer is able to benefit
from their right to use the applicable licensed technology.
Amounts
Recognized in the Consolidated Balance Sheet at June 30, 2022
Noncurrent liabilities
$
i19
/
For
the six-month period ended June 30, 2022, we recognized revenue of $i56 million in the "Sales and other operating revenues" line on our consolidated income statement. iNo
revenue was recognized during the three-month period ended June 30, 2022. We expect to recognize the contract liabilities as of June 30, 2022, as revenue during 2026.
i
Note 17—Segment Disclosures and
Related Information
We explore for, produce, transport and market crude oil, bitumen, natural gas, LNG and NGLs on a worldwide basis. We manage our operations through isix operating segments, which are primarily defined by geographic region: Alaska; Lower 48; Canada; Europe, Middle East and North Africa; Asia Pacific; and Other International.
Corporate and Other represents income and costs not directly associated with an operating segment, such as most interest income and expense; premiums
on early retirement of debt; corporate overhead and certain technology activities, including licensing revenues; and unrealized holding gains or losses on equity securities. Corporate assets include all cash and cash equivalents and short-term investments.
We evaluate performance and allocate resources based on net income (loss). Intersegment sales are at prices that approximate market.
Our effective tax rate for the three-month periods ended June 30, 2022 and 2021 was i32.8
percent and i32.1 percent, respectively, and our effective tax rate for the six-month periods ended June 30, 2022 and 2021 was i29.9
percent and i35.9 percent, respectively. Our effective tax rate for the first six-months of 2022 was impacted by the shift of income among our taxing jurisdictions, the release of tax reserves related to the closing of an IRS audit, a change to our valuation allowance, and the impact of the interest deduction related to our debt exchange, as described below.
In the first quarter of 2022, the IRS closed the 2017 audit of our U.S. federal income tax return. As a result,
we recognized federal and state tax benefits totaling $i515 million relating to the recovery of outside tax basis previously offset by a full reserve.
During the second quarter of 2022, Norway enacted changes to the Petroleum Tax System. As a result of the enactment, a valuation allowance of $i58 million
was recorded during the quarter to reflect changes to our ability to realize certain deferred tax assets under the new law.
For the three- and six-month periods of 2022, our valuation allowance increased by $i58 million and $i5
million, respectively, compared to a decrease of $i87 million and $i151
million for the same periods of 2021. The increase in the three- and six-month periods of 2022 relate to the Norway tax law change described above. In addition, our six-month periods of 2022 and of 2021 include impacts from changes in our valuation allowance related to the fair value measurement of our CVE common shares and our expectation of the tax impact related to incremental capital gains and losses.
Our 2022 and 2021 effective tax rates were adversely impacted by $i37
million and $i75 million, respectively, due to incremental interest deductions from debt exchanges in both periods offsetting U.S. foreign source revenue that would otherwise have been offset by foreign tax credits. See Note 6.
The
Company has ongoing income tax audits in a number of jurisdictions. The government agents in charge of these audits regularly request additional time to complete audits, which we generally grant, and conversely occasionally close audits unpredictably. Within the next twelve months we may have audit periods close that could significantly impact our total unrecognized tax benefits. The amount of such change is not estimable but could be significant when compared with our total unrecognized tax benefits.
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
Management’s Discussion and Analysis is the
company’s analysis of its financial performance and of significant trends that may affect future performance. It should be read in conjunction with the financial statements and notes. It contains forward-looking statements including, without limitation, statements relating to the company’s plans, strategies, objectives, expectations and intentions that are made pursuant to the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995. The words “anticipate,”“believe,”“budget,”“continue,”“could,”“effort,”“estimate,”“expect,”“forecast,”“goal,”“guidance,”“intend,”“may,”“objective,”“outlook,”“plan,”“potential,”“predict,”“projection,”“seek,”“should,”“target,”“will,”“would”
and similar expressions identify forward-looking statements. The company does not undertake to update, revise or correct any of the forward-looking information unless required to do so under the federal securities laws. Readers are cautioned that such forward-looking statements should be read in conjunction with the company’s disclosures under the heading: “CAUTIONARY STATEMENT FOR THE PURPOSES OF THE ‘SAFE HARBOR’ PROVISIONS OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995,” beginning on page 53.
The terms “earnings” and “loss” as used in Management’s Discussion and Analysis refer to net
income (loss).
Business Environment and Executive Overview
ConocoPhillips is the world’s largest independent E&P company with operations and activities in 13 countries. Our diverse, low cost of supply portfolio includes resource-rich unconventional plays in North America; conventional assets in North America, Europe, and Asia; LNG developments; oil sands in Canada; and an inventory of global conventional and unconventional exploration prospects. Headquartered in Houston, Texas, at June 30, 2022, we employed approximately 9,400 people worldwide and had total assets of $94 billion.
Overview
Commodity
prices continued to increase during the second quarter of 2022, in part due to the continued impacts associated with the Russian invasion of Ukraine and sanctions levied against Russia as a result of the conflict. We anticipate that prices will continue to be cyclical and volatile, and our view is that a successful business strategy in the E&P industry must be resilient in lower price environments, while also retaining full upside exposure during periods of higher prices. As such, we are unhedged, remain highly disciplined in our investment decisions and continue to monitor market fundamentals including the impacts associated with the conflict in Ukraine, OPEC plus supply updates, global demand for our products, oil and gas inventory levels, inflation, supply chain disruptions and the fluctuating global COVID-19 impacts.
The macro-environment, including the energy transition, also continues to evolve. We believe ConocoPhillips
is playing a valued role in the energy transition. We are guided by our triple mandate that simultaneously calls for us to reliably and responsibly deliver oil and gas production to meet energy transition pathway demand, deliver competitive returns on and of capital, and do so with a resilient and sustainable portfolio enabling us to achieve our net-zero operating emissions ambition. Our triple mandate is supported by financial principles and capital allocation priorities designed to allow us to deliver superior returns through the price cycles. Our financial principles consist of maintaining balance sheet strength, providing peer-leading distributions, making disciplined investments and demonstrating ESG leadership, all of which are in service to generating competitive financial returns through the price cycles.
In the second quarter, total company production was 1,692 MBOED, resulting in cash provided by
operating activities of $7.9 billion, with $1 billion returned to shareholders through our ordinary dividend and a VROC and $2.3 billion through share repurchases. We ended the quarter with cash, cash equivalents and short-term investments totaling $8.2 billion.
In May 2022, we announced an increase to our 2022 expected distributions through our three-tier return of capital framework to $10 billion for the year. Additionally, in August we increased our targeted distributions further, to a new total of $15 billion for the year. This framework includes our ordinary dividend, share repurchases and the VROC tier that was introduced last December. In August, we declared our third quarter ordinary dividend of $0.46 per share and a fourth quarter VROC payment of $1.40 per share.
Demonstrating our commitment to enhance balance sheet strength, in May 2022, we retired $1,250 million principal amount of our 4.95 percent Notes due 2026 and $500 million principal amount of floating rate notes. Both retirements were sourced from available cash. Additionally, in the first quarter we executed a debt refinancing comprised of concurrent transactions including new debt
issuances, a cash tender offer and debt exchange offers. In aggregate, these transactions reduced the company's total debt by $3 billion. These activities facilitate our ability to achieve our previously announced $5 billion debt reduction target by the end of 2026, while also reducing the company's annual cash interest expense. See Note 6.
In 2022, we have taken several steps to expand our global LNG business. In the first quarter, we increased our equity share in Asia Pacific LNG (APLNG). In the second quarter, we signed an
agreement for a new joint venture with QatarEnergy that will participate with a 12.5 percent interest in the North Field East LNG project. Subject to regulatory approvals, we will hold a 25 percent interest in this joint venture. Domestically, in July 2022, we announced a Heads of Agreement (HOA) with Sempra to potentially acquire a 30 percent direct equity holding in Port Arthur Liquefaction Holdings, LLC and an LNG offtake equivalent to approximately 5 million tonnes per annum from the Port Arthur LNG project. The HOA is a preliminary, non-binding arrangement, with development of the Port Arthur LNG project subject to concluding definitive agreements and resolving a number of risks and uncertainties, including, among others, signing engineering and construction contracts, obtaining financing and reaching a final investment decision between the parties.
As
part of our ongoing portfolio high-grading and optimization efforts, in April 2022, we completed the sale of certain noncore assets in the Lower 48 segment for $370 million after customary adjustments. In July 2022, we entered into agreements to sell our interests in additional noncore assets in the Lower 48 segment for $265 million, before customary adjustments. These transactions are expected to close in the third quarter of 2022. See Note 3.
Operationally, we remain focused on safely executing the business. Production was 1,692 MBOED in the second quarter of 2022, an increase of 104 MBOED from the same period a year ago. After adjusting for closed acquisitions and dispositions and the conversion of previously acquired
Concho contracted volumes from a two-stream to a three-stream basis, second-quarter 2022 production decreased by 69 MBOED or 4 percent from the same period a year ago. Organic growth from Lower 48 and other development programs more than offset decline; however, production was lower overall primarily due to planned and unplanned downtime.
We re-invested $2 billion into the business in the form of capital expenditures and investments during the second quarter of 2022, with over half of the expenditures focused on flexible, short-cycle unconventional plays in the Lower 48 segment, where our production has access to both domestic and export markets.
In further support of our commitment to ESG leadership and excellence, in July 2022, we announced that ConocoPhillips joined the Oil and Gas Methane Partnership (OGMP) 2.0 initiative. The initiative's
mission is to improve industry transparency in methane emissions reporting and encourage progress in reducing those emissions. We believe that applying the rigorous OGMP 2.0 reporting standards across our global assets will be a vital step towards meeting our Paris-aligned climate-risk commitments, including our net-zero ambition for operational emissions by 2050, and will allow us to credibly demonstrate how we are delivering against our methane improvement objectives and targets.
Commodity prices are the most significant factor impacting our profitability and related returns on and of capital to our shareholders. Dynamics that could influence world energy markets and commodity prices are global economic health, supply or demand disruptions or fears thereof caused by civil unrest, global pandemics, military conflicts, actions taken by OPEC plus and other major oil producing countries, environmental laws, tax regulations, governmental policies and weather-related disruptions. Our strategy is to create value through price cycles by delivering on the financial, operational and ESG priorities that underpin our value
proposition.
Our earnings and operating cash flows generally correlate with price levels for crude oil and natural gas, which are subject to factors external to the company and over which we have no control. The following graph depicts the trend in average benchmark prices for WTI crude oil, Brent crude oil and Henry Hub natural gas:
Brent crude oil prices averaged $113.78 per barrel in the second quarter of 2022, an increase of 65 percent compared with $68.83 per barrel in the second quarter of 2021. WTI at Cushing crude oil prices averaged $108.41 per barrel in the second quarter of 2022, an increase of 64 percent compared with $66.07 per barrel in the
second quarter of 2021. Oil prices increased as a result of the ongoing global economic recovery following COVID-related impacts as well as supply constraints due to Russia's invasion of Ukraine, OPEC plus adherence to agreed production quotas, other disruptions and supply chain bottlenecks limiting growth.
Henry Hub natural gas prices averaged $7.17 per MMBTU in the second quarter of 2022, an increase of 153 percent compared with $2.83 per MMBTU in the second quarter of 2021. Henry Hub prices have increased due to low inventories, healthy domestic demand and strong exports via pipelines and LNG.
Our realized bitumen price averaged $75.42 per barrel in the second quarter of 2022, an increase of 101 percent compared with $37.60 per barrel in the second quarter of 2021. The increase in the second quarter of 2022 was driven by higher blend prices for Surmont sales, largely
attributed to a strengthening of WTI price. We continue to optimize bitumen price realizations through the utilization of downstream transportation solutions and implementation of alternate blend capability which results in lower diluent costs.
For the second quarter of 2022 our total average realized price increased to $88.57 per BOE compared with
Significant items during the second quarter of 2022 and recent announcements included the following:
•Announced a $5 billion increase in expected 2022 returns of capital to shareholders to a total of $15 billion.
•Distributed $3.3 billion to shareholders through a three-tier framework, including $1.0 billion in cash through the ordinary dividend and VROC and $2.3 billion through share repurchases.
•Expanded global LNG portfolio
through participation in QatarEnergy's North Field East LNG project and announced a non-binding Heads of Agreement with Sempra Infrastructure with opportunities to participate in large-scale LNG projects, an LNG offtake of approximately 5 million tonnes per annum and related carbon capture activities.
•As part of our ongoing commitment to ESG excellence and leadership, we joined the OGMP 2.0 initiative.
•Generated cash provided by operating activities of $7.9 billion.
•Delivered second-quarter production of 1,692 MBOED while successfully completing planned maintenance turnarounds.
•Continued progress toward the company's
$5 billion debt reduction target through $1.8 billion of debt retirements during the quarter, now totaling $3 billion since announcing the target.
•Completed $0.4 billion of noncore asset sales during the quarter.
•Ended the quarter with cash, cash equivalents and restricted cash of $7.2 billion and short-term investments of $1.3 billion.
Outlook
Capital and Production
Third-quarter 2022 production is expected to be 1.70 to 1.76 MBOED, reflecting the impacts of seasonal turnarounds planned primarily in Alaska and the Asia Pacific region. Full-year
production is expected to be approximately
1.74 MMBOED reflecting uncertainty in Libya and modest updates across the portfolio.
Guidance regarding capital is unchanged.
Depreciation, Depletion and Amortization
Full-year guidance for depreciation, depletion and amortization has decreased to $7.6 billion.
Unless otherwise indicated, discussion of results for the three- and six-month periods ended June 30, 2022, is based on a comparison with the corresponding period of 2021.
Consolidated Results
A summary of the company's net income (loss) by business segment follows:
Millions
of Dollars
Three Months Ended June 30
Six Months Ended June 30
2022
2021
2022
2021
Alaska
$
687
371
1,271
530
Lower
48
3,581
1,175
6,371
1,643
Canada
316
102
607
112
Europe, Middle East and North Africa
385
207
797
360
Asia
Pacific
525
175
1,661
492
Other International
—
(5)
—
(9)
Corporate and Other
(349)
66
197
(55)
Net
income
$
5,145
2,091
10,904
3,073
Net income in the second quarter of 2022 increased $3,054 million. Second quarter earnings were positively impacted by:
•Higher realized commodity prices.
•Higher sales volumes, primarily due to our Shell Permian acquisition, partly offset by assets divested. See
Note 3.
•Higher equity in earnings of affiliates, primarily due to higher LNG sales prices.
•Gain on dispositions primarily due the divestiture of noncore assets in the Lower 48 segment and recognizing higher contingent payments related to prior dispositions in our Canada and Lower 48 segments.See Note 3.
Second quarter 2022 earnings were negatively impacted by:
•Higher production and operating
expenses and taxes other than income taxes, primarily due to higher prices and production volumes.
•Higher income tax provision.
•Absence of mark to market gains associated with Cenovus Energy (CVE) shares. See Note 5.
Net income in the six-month period ended June 30, 2022, increased $7,831 million. In addition to the items mentioned above, earnings in the six-month period were positively impacted by:
•Previously unrecognized
$515 million tax benefit related to the closing of an IRS audit in the first quarter.
•Gain on dispositions primarily due to a $462 million after-tax gain related to the divestiture of our Indonesia assets. See Note 3.
•Absence of restructuring and transaction
expenses of $243 million after-tax related to our Concho acquisition.
•Absence of realized losses on hedges of $233 million after-tax related to derivative positions acquired in our Concho acquisition. See Note 10.
•Lower DD&A expenses caused by lower rates driven by price-related reserve revisions due to higher commodity prices, partially offset by higher production volumes.
•After-tax gain of $62 million associated with refinancing transactions. See
Note 6.
In addition to the items mentioned above, earnings in the six-month period were negatively impacted by:
•Absence of $194 million after-tax gain recognized in conjunction with our Australia-West divestiture. See Note 9.
Unless otherwise indicated, all results in Income Statement Analysis are before-tax.
Sales and other operating revenues for the three-
and six-month periods of 2022 increased $11,605 million and
$19,541 million, respectively, mainly due to higher realized commodity prices and higher sales volumes.
Equity in earnings of affiliates for the three- and six-month periods of 2022 increased $385 million and $689 million, respectively, primarily due to higher earnings driven by higher LNG and crude prices as well as higher sales volumes inclusive of the additional 10 percent interest in APLNG we acquired in the first quarter of 2022. See Note 3.
Gain on dispositions in the second quarter of 2022 increased due to a gain of $80 million
for the sale of noncore assets in the Lower 48 segment. For the six-month period of 2022, we recognized a gain of $534 million from our Indonesia divestiture. For both the three- and six-month periods of 2022, we recognized higher contingent payments associated with previous dispositions in our Canada and Lower 48 segments than the same periods of 2021. Offsetting the increase in gains in the six-month period of 2022 was the absence of a $200 million gain associated with our Australia-West divestiture recognized in the first quarter of 2021. See Note 3.
Other income for the three- and six-month periods of 2022 decreased $415 million and $507 million, respectively, primarily due to the absence
of mark to market gains associated with our CVE common shares which were fully divested in the first quarter of 2022. See Note 5.
Purchased commodities for the three- and six-month periods of 2022 increased $6,236 million and $8,504 million, respectively, primarily due to higher gas and crude prices and volumes.
Production and operating expenses for the three- and six-month periods of 2022 increased $362 million and $560 million, respectively, primarily due to higher production volumes.
Selling, general and administrative expenses decreased $145 million in the
six-month period primarily due to the absence of transaction and restructuring expenses associated with our Concho acquisition in 2021.
DD&A for the three- and six-month periods of 2022 decreased $57 million and $120 million, respectively, mainly due to lower rates from positive price-related reserve revisions and the absence of DD&A from disposed assets offset by higher overall production volumes primarily associated with our Shell Permian acquisition.
Taxes other than income taxes for the three- and six-month periods of 2022 increased $639 million and $1,083 million, respectively, caused by higher commodity prices and higher production volumes.
Other expenses for the second quarter of 2022 increased $49 million primarily related to premiums
paid to repurchase debt. For the six-month period of 2022, other expenses decreased $111 million primarily related to a gain of $127 million associated with extinguishment of debt from the first quarter of 2022. See Note 6.
See Note 18—Income Taxesfor information regarding our Income tax provision and effective tax rate.
We explore for, produce, transport and market crude oil, bitumen, natural gas, LNG and NGLs on a worldwide basis. In the quarter ending June 30, 2022, our operations were producing in the U.S., Norway, Canada, Australia, China, Malaysia, Qatar and Libya.
Total production of 1,692 MBOED increased
104 MBOED or 7 percent in the second quarter of 2022 and 162 MBOED or 10 percent in the six-month period of 2022, primarily due to:
•New wells online in the Lower 48, Alaska, Malaysia and Canada.
•Higher volumes in the Lower 48 due to our Shell Permian acquisition.
•Conversion of previously acquired Concho contracted volumes from a two-stream to a three-stream basis.
Production increases in the second quarter and in the six-month period of 2022 were partly offset due to:
•Normal field decline.
•Divestitures of Indonesia and noncore assets in the Lower 48 segment.
Production
for the second quarter of 2022 was 1,692 MBOED, an increase of 104 MBOED from the same period a year ago. After adjusting for closed acquisitions and dispositions and the conversion of previously acquired Concho contracted volumes from a two-stream to a three-stream basis, second-quarter 2022 production decreased by 69 MBOED or 4 percent from the same period a year ago. Organic growth from Lower 48 and other development programs more than offset decline; however, production was lower overall primarily due to planned and unplanned downtime.
Production for the first six months of 2022 was 1,720 MBOED, an increase of 162 MBOED from the same period a year ago. After adjusting for closed acquisitions and dispositions, the conversion of previously acquired Concho contracted volumes from a two-stream to a three-stream basis, and 2021 Winter Storm Uri impacts, production decreased
53
MBOED or 3 percent from the same period a year ago. Organic growth from Lower 48 and other development programs more than offset decline; however, production was lower overall primarily due to planned and unplanned downtime.
The
Alaska segment primarily explores for, produces, transports and markets crude oil, NGLs and natural gas. As of June 30, 2022, Alaska contributed 18 percent of our consolidated liquids production and two percent of our consolidated natural gas production.
Net Income
Earnings from Alaska increased $316 million and $741 million in the three- and six-month periods of 2022, respectively. Increases to earnings include:
•Higher realized crude oil prices.
Offsets to the earnings increase include:
•Higher taxes other than income taxes associated with higher realized crude oil prices.
In addition to the items detailed
above, in the six-month period of 2022, earnings also increased due to:
•Lower DD&A expenses primarily driven by lower rates from price-related reserve revisions and lower production.
Production
Average production decreased slightly in the three- and six-month periods of 2022, respectively. Decreases to production include:
•Normal field decline.
•Higher downtime and lower base performance primarily in our Greater Kuparuk Area.
Offsets to the production decreases include:
•New wells online at our Western North Slope assets.
*2022 includes the conversion of previously acquired Concho two-stream contracts to three-stream initiated in the fourth quarter of 2021.
The Lower 48 segment consists of operations located in the U.S. Lower 48 states, as well as producing properties in the Gulf of Mexico. As of June 30, 2022, the Lower 48 contributed 67 percent of our consolidated liquids production
and
71 percent of our consolidated natural gas production.
Net Income
Earnings from the Lower 48 increased $2,406 million and $4,728 million in the three- and six-month periods of 2022, respectively. Increases to earnings include:
•Higher realized prices.
•Higher sales volumes of crude oil and NGLs primarily related to our Shell Permian Acquisition. See Note 3.
•After-tax gains on disposition of $63 million related to the sale of certain noncore
assets as well as contingent payments of $16 million and $32 million in the three- and six-month periods of 2022, respectively, associated with previous asset sales. See Note 3.
Offsets to the earnings increase include:
•Higher production and operating expenses, taxes other than income taxes and DD&A expenses primarily due to higher production volumes. Partially offsetting the increase in DD&A expenses were lower rates from price-related reserve revisions.
In addition to the items detailed above, in the six-month period of 2022, earnings also increased due to the absence of realized
losses on hedges related to derivative positions acquired in our Concho acquisition. See Note 10.
Production
Average production increased 183 MBOED and 217 MBOED in the three- and six-month periods of 2022, respectively. Increases to production include:
•New wells online from our development programs in Permian, Eagle Ford and Bakken.
•Higher volumes due to our Shell Permian acquisition. See
Note 3.
•Conversion of previously acquired Concho contracted volumes from a two-stream to a three-stream basis.
Offsets to the production increases include:
•Normal field decline.
Completed and Planned Dispositions
On April 1, 2022, we completed our divestiture of certain noncore assets for $370 million, after customary adjustments. Production from these assets averaged approximately 10 MBOED in the three-months ended March 31, 2022. In July 2022, we entered into agreements to sell our interests in certain noncore assets
in the Lower 48 segment for $265 million, before customary adjustments. These transactions are expected to close in the third quarter of 2022. See Note 3.
Average
sales prices include unutilized transportation costs.
Our Canadian operations mainly consist of the Surmont oil sands development in Alberta and the liquids-rich Montney unconventional play in British Columbia. As of June 30, 2022, Canada contributed one percent of our consolidated liquids production and three percent of our consolidated natural gas production.
Net Income
Earnings from Canada increased $214 million and $495 million in the three- and six-month periods of 2022, respectively. Increases to earnings include:
•Higher realized prices.
•Higher after-tax gains on disposition related to contingent payments of $118 million and $294 million in the three- and six-month
periods of 2022, respectively, associated with the prior sale of certain assets to CVE, compared with $52 million and $72 million in the same periods of 2021, respectively. See Note 3.
Offsetting the earnings increases were lower sales volumes.
Production
Average production decreased 17 MBOED and 15 MBOED in the three- and six-month periods of 2022, respectively. Decreases to production include:
•Normal field decline.
•Planned turnaround at the Surmont Central Processing Facility 1 during the second quarter
of 2022.
•Higher royalty rates across the segment due to higher commodity prices.
The
Europe, Middle East and North Africa segment consists of operations principally located in the Norwegian sector of the North Sea and the Norwegian Sea, Qatar, Libya and commercial operations in the U.K. During the current period, we have increased our capacity and supply arrangements on future gas purchases, which are primarily offset by future gas sales contracts, primarily in Europe. As of June 30, 2022, our Europe, Middle East and North Africa operations contributed nine percent of our consolidated liquids production and 16 percent of our consolidated natural gas production.
Net Income
Earnings from Europe, Middle East and North Africa increased by $178 million and $437 million in the three- and
six-month periods of
2022, respectively. Increases to earnings include:
•Higher realized prices.
•Higher LNG sales prices, reflected in equity in earnings of affiliates.
•Foreign exchange gains as the USD strengthened against the Norwegian Kroner.
Offsetting the earnings increases include:
•Lower sales volumes primarily due to turnaround activity in Norway in the second quarter.
•Changes to the Petroleum Tax System in Norway. See Note 18.
In
addition to the items detailed above, in the six-month period of 2022, earnings impacts include:
•Increase due to lower DD&A expenses primarily driven by lower volumes and lower rates from price-related reserve revisions.
•Decrease due to lower sales volumes primarily due to turnaround activity in Qatar in the first quarter, reflected in equity in earnings of affiliates.
Average consolidated production decreased 29 MBOED and 15 MBOED in the three- and six-month periods of 2022, respectively. Decreases to production include:
•Fieldwide turnarounds in the Greater Ekofisk Area of Norway in the second quarter of 2022.
•Normal field decline.
•Curtailed production in Libya due to the force majeure at the Es Sider export terminal in June.
Offsets to the production decreases
include:
•New wells online and improved performance in Norway.
Force Majeure in Libya
Production ceased the last week of June 2022, due to a forced shutdown of the Es Sider export terminal after a period of civil unrest. Force majeure was lifted on July 15, 2022, and production has resumed.
Exploration Activity
Three wells from our 2022 four well exploration and appraisal campaign in Norway have been drilled and determined to be dry holes, increasing exploration expenses by approximately $76 million including the Slagugle appraisal well, which is in an area we are continuing to evaluate.
The
Asia Pacific segment has operations in China, Malaysia, Australia and commercial operations in Singapore and Japan. As of June 30, 2022, Asia Pacific contributed five percent of our consolidated liquids production and eight percent of our consolidated natural gas production.
Net Income
Earnings from Asia Pacific increased $350 million and $1,169 million in the three- and six-month periods of 2022, respectively. Increases to earnings include:
•Higher equity in earnings of affiliates reflecting higher LNG sales prices as well as our increased interest in APLNG.
•Higher realized crude oil prices.
•Lower DD&A expenses associated with lower
production volumes due to the divestiture of our Indonesia assets and lower rates from positive price-related reserve revisions.
Offsets to the earnings increase include:
•Lower sales volumes primarily due to the divestiture of our Indonesia assets.
•Higher taxes other than income taxes primarily due to higher realized crude oil prices.
In addition to the items detailed above, in the six-month period of 2022, earnings impacts include:
•Increase due to an after-tax gain of $534 million associated with the divestiture of our Indonesia assets. See Note 3.
•Decrease
due to absence of an after-tax gain of $200 million recognized in the first quarter of 2021 related to a contingent payment from our Australia-West divestiture in 2020.See Note 9.
Consolidated Production
Average consolidated production decreased 63 MBOED and 42 MBOED in the three- and six-month periods of 2022, respectively. Decreases to production include:
•Divestiture of our Indonesia assets in the first quarter of 2022.
•Normal field decline.
•Decrease
in crude oil entitlement percentage and PSC adjustments in Malaysia.
Offsets to the production decreases includes Bohai Bay development activity in China.
Asset Acquisitions and Dispositions
In the first quarter of 2022, we completed the acquisition of an additional 10 percent interest in APLNG increasing our ownership to 47.5 percent. Also in the first quarter, we completed the divestiture of our subsidiaries that held our Indonesia assets and operations. Production from the disposed assets averaged approximately 33 MBOED in the
The Other International segment consists of exploration and appraisal activities in Colombia as well as contingencies associated with prior operations in other countries. As a result of recent acquisitions, we refocused our exploration program and announced our intent to pursue managed exits from certain areas.
Earnings from our Other International operations improved $5 million in the second quarter of 2022 and $9 million in the six-month period ended June
30, 2022, compared with the same periods of 2021.
Corporate and Other
Millions of Dollars
Three Months Ended June 30
Six Months
Ended June 30
2022
2021
2022
2021
Net Income (Loss)
Net interest expense
$
(164)
(181)
(382)
(451)
Corporate
general and administrative expenses
(16)
(65)
(95)
(194)
Technology
(9)
(4)
49
37
Other income (expense)
(160)
316
625
553
$
(349)
66
197
(55)
Net
interest expense consists of interest and financing expense, net of interest income and capitalized interest. Net interest expense improved by $17 million and $69 million in the three- and six-month periods of 2022, respectively, primarily as a result of our debt reduction transactions. Improvement in the six-month period also includes the absence of a prior year tax adjustment.
Corporate G&A expenses include compensation programs and staff costs. These expenses decreased by $49 million and $99 million in the three- and six-month periods ended June 30, 2022, respectively, due to mark to market adjustments associated with certain compensation programs. Additionally, in the six-month period of 2022 Corporate G&A expenses decreased due to the absence of restructuring expenses associated with our 2021 acquisition of Concho Resources Inc.
Technology
includes our investment in new technologies or businesses, as well as licensing revenues. Activities are focused on both conventional and tight oil reservoirs, shale gas, heavy oil, oil sands, enhanced oil recovery, as well as LNG. See Note 16.
Other income (expense) or “Other” includes certain corporate tax-related items, foreign currency transaction gains and losses, environmental costs associated with sites no longer in operation, other costs not directly associated with an operating segment, gains/losses on the early retirement of debt, holding gains or losses on equity securities, and pension settlement expense. In the second quarter of 2022, “Other” decreased $476 million primarily due to the
absence of unrealized gains associated with our CVE common shares which were fully divested in the first quarter of 2022 and premiums paid to repurchase debt. For the six-month period of 2022, "Other" increased $72 million. In addition to the items mentioned previously, during the first quarter of 2022, the IRS closed the 2017 audit of our U.S. federal income tax return, resulting in $474 million federal tax benefit. Also in the first quarter, we recognized an after-tax gain of $62 million associated with the debt restructuring transactions, partly offset by a $101 million tax impact associated with the disposition of our Indonesia assets. See Note 5 for information on our CVE common shares, Note 18for information about the tax benefit, Note 6for information regarding debt and Note 3for information on our Indonesia divestiture.
To meet our short-and long-term liquidity requirements, we look to a variety of funding sources, including cash generated from operating activities, our commercial paper and credit facility programs, and our ability to sell securities using our shelf registration statement. During the first six months of 2022, the primary uses of our available cash were
$5.1 billion to support our ongoing capital expenditures and investments program, $3.7 billion to repurchase common stock, $2.9 billion net to reduce debt as part of refinancing transactions and retirements, $1.9 billion to pay dividends, including the ordinary dividend and a VROC, and $1.1 billion net purchases of investments.
At June 30, 2022, we had total liquidity of $13.7 billion, including cash
and cash equivalents of $6.9 billion, short-term investments of $1.3 billion, and available borrowing capacity under our credit facility of $5.5 billion. We believe current cash balances and cash generated by operating activities, together with access to external sources of funds as described below in the “Significant Changes in Capital” section, will be sufficient to meet our funding requirements in the near- and long-term, including our capital spending program, acquisitions, dividend payments and debt obligations.
Significant Changes in Capital
Operating Activities
Cash provided by operating activities was $13.0 billion for the
first six months of 2022, compared with $6.3 billion for the corresponding period of 2021. The increase in cash provided by operating activities is primarily due to higher realized commodity prices, higher sales volumes mostly due to our acquisition of Shell Permian assets, and the absence of the 2021 settlement of all oil and gas hedging positions acquired from Concho.The increase in cash provided by operating activities was partly offset by the timing of Libya tax and royalty payments occurring in the first quarter of 2022 as well as U.S. tax payments in the second quarter.
Our short- and long-term operating cash flows are highly dependent upon prices for crude oil, bitumen, natural gas, LNG and NGLs. Prices and margins in our industry have historically been volatile and are driven by market conditions over which we have no control. Absent other mitigating factors, as these
prices and margins fluctuate, we would expect a corresponding change in our operating cash flows.
The level of production volumes, as well as product and location mix, impacts our cash flows. Future production is subject to numerous uncertainties, including, among others, the volatile crude oil and natural gas price environment, which may impact investment decisions; the effects of price changes on production sharing and variable-royalty contracts; acquisition and disposition of fields; field production decline rates; new technologies; operating efficiencies; timing of startups and major turnarounds; political instability; impacts of a global pandemic; weather-related disruptions; and the addition of proved reserves through exploratory success and their timely and cost-effective development. While we actively manage for these factors,
production levels can cause variability in cash flows, although generally this variability has not been as significant as that caused by commodity prices.
To maintain or grow our production volumes, we must continue to add to our proved reserve base. See the “Capital Expenditures and Investments” section.
For the first six months of 2022, we invested $5.1 billion in capital expenditures and investments; $1.4 billion of which was acquisition capital for the additional 10 percent interest in APLNG, and the remainder funding our operating capital program. Our 2022 operating plan capital expenditures are currently expected to be $7.8 billion. This guidance excludes $1.4 billion of capital associated with increasing our APLNG interest.Our 2021 capital expenditures and investments were $5.3 billion. See the “Capital Expenditures and Investments”
section.
In May 2021, we initiated the monetization of our investment in CVE common shares with the plan to direct proceeds toward our existing share repurchase program. We began disposing of our CVE shares in May 2021, and by the end of the first quarter, we fully divested of our investment, recognizing proceeds of $1.4 billion in the first quarter of 2022. Since inception, we have generated total proceeds of $2.5 billion. See Note 5. Other proceeds from dispositions received in the current year include our divestitures in Asia Pacific and Lower 48 segments for approximately $1.1 billion after customary adjustments and $362 million in contingent payments associated with prior divestitures. See
Note 3.
In April 2022, we completed the sale of certain noncore assets in the Lower 48 segment for $370 million after customary adjustments. In July 2022, we entered into agreements to sell our interests in additional noncore assets in the Lower 48 segment for $265 million, before customary adjustments. These transactions are expected to close in the third quarter of 2022.
We invest in short-term investments as part of our cash investment strategy, the primary objective of which is to protect principal, maintain liquidity and provide yield and total returns; these investments include time deposits, commercial paper, as well as debt securities classified as available for sale. Funds for short-term needs to support our operating plan and provide resiliency to react to short-term price volatility are invested in highly liquid instruments with maturities within the
year. Funds we consider available to maintain resiliency in longer term price downturns and to capture opportunities outside a given operating plan may be invested in instruments with maturities greater than one year.
Investing activities in the first six months of 2022 included net purchases of $1,104 million of investments. We had net purchases of $640 million of short-term instruments and $464 million of long-term instruments. See Note 13.
Financing Activities
In February 2022, we refinanced our revolving credit facility from a total aggregate principal amount of $6.0 billion to $5.5 billion with an expiration date of February 2027. The credit facility may be used for direct bank borrowings, the issuance of
letters of credit totaling up to $500 million, or as support for our commercial paper program. With no commercial paper outstanding and no direct borrowings or letters of credit, we had access to $5.5 billion in available borrowing capacity under our revolving credit facility at June 30, 2022.
Our debt balance at June 30, 2022, was $17.0 billion compared with $19.9 billion at December 31, 2021. The current portion of debt, including payments for finance leases, is $0.7 billion. Payments will be made using current cash balances and cash generated by operating activities. In the second quarter of 2022, we repurchased notes and retired floating rate debt and in the first quarter of 2022, we executed a debt refinancing
comprised of concurrent transactions including new debt issuances, a cash tender offer and debt exchange offers. In aggregate, the transactions reduced the company's total debt by $3.0 billion. The refinancing facilitates our ability to achieve our previously announced $5 billion debt reduction target by the end of 2026 while also reducing the company's annual cash interest expense.
The current credit ratings on our long-term debt are:
•Fitch: “A” with a “stable” outlook
•S&P: “A-” with a “stable” outlook
•Moody’s: “A3”
with a “positive” outlook
See Note 6 for additional information on debt, revolving credit facility and credit ratings.
Certain of our project-related contracts, commercial contracts and derivative instruments contain provisions requiring us to post collateral. Many of these contracts and instruments permit us to post either cash or letters of credit as collateral. At June 30, 2022 and December 31,
2021, we had direct bank letters of credit of $320 million and $337 million, respectively, which secured performance obligations related to various purchase commitments incident to the ordinary conduct of business. In the event of credit ratings downgrades, we may be required to post additional letters of credit.
We have a universal shelf registration statement on file with the SEC under which we have the ability to issue and sell an indeterminate number of various types of debt and equity securities.
Capital Requirements
For information about our capital expenditures and investments, see the “Capital Expenditures and Investments” section.
In 2021, as part of our objective to maintain a strong
balance sheet, we announced our intention to reduce our total debt by $5 billion by 2026. In the first half of 2022, we executed concurrent debt refinancing transactions, repurchased existing notes, and retired floating rates notes upon natural maturity, that in aggregate reduced the company's total debt by
$3 billion and progressed the achievement of our debt reduction target while also lowering our annual cash interest expense and extending the weighted average maturity of our debt portfolio. See Note 6.
In December 2021, we announced our expected 2022 return of capital program and the initiation of a three-tier return of capital framework. The framework is structured
to deliver a compelling, growing ordinary dividend and through-cycle share repurchases. In addition to the ordinary dividend and share repurchases, beginning in December 2021, the framework includes the addition of a discretionary VROC tier. The VROC will provide a flexible tool for meeting our commitment of returning greater than 30 percent of cash from operating activities during periods where commodity prices are meaningfully higher than our planning price range. Our expected 2022 total capital return is $15 billion, an increase of $5 billion from our previously announced target.
In the first six months of 2022, we paid ordinary dividends of $0.92 per common share. In addition, we paid VROC dividends of $0.50 per common share for dividends declared in the fourth quarter of 2021 and the first quarter of 2022. In the first six months of 2021, we paid ordinary dividends of $0.86 per common share. On August 4,
2022, we declared both a third-quarter ordinary dividend and a fourth-quarter VROC. The ordinary dividend is $0.46 per share payable September 1, 2022, to shareholders of record on August 16, 2022. The VROC is $1.40 per share, payable October 14, 2022 to shareholders of record on September 29, 2022
In late 2016, we initiated our current share repurchase program with Board of Director’s authorization of $25 billion of our common stock. As of June 30, 2022, share repurchases since the inception of our current program totaled 285 million shares and $17.9 billion. In the six months ended June 30, 2022, we repurchased
37.7 million shares for a cost of
$3.7 billion. Repurchases are made at management’s discretion, at prevailing prices, subject to market conditions and other factors.
See Part I—Item 1A—Risk Factors – “Our ability to execute our capital return program is subject to certain considerations” in our 2021 Annual Report on Form 10-K.
We have various cross guarantees among our Obligor group; ConocoPhillips, ConocoPhillips Company and Burlington Resources LLC, with respect to publicly held debt securities. ConocoPhillips Company is 100 percent owned by ConocoPhillips. Burlington Resources LLC is 100 percent owned by ConocoPhillips Company. ConocoPhillips and/or ConocoPhillips Company have fully and unconditionally guaranteed the payment obligations of Burlington Resources LLC, 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 tables present summarized financial information for the Obligor Group, as defined below:
•The Obligor Group will reflect guarantors and issuers of guaranteed securities consisting of ConocoPhillips, ConocoPhillips Company and Burlington Resources LLC.
•Consolidating adjustments for elimination of investments in and transactions between the collective guarantors and issuers of guaranteed securities are reflected in the balances of the summarized financial information.
•Non-Obligated Subsidiaries are excluded from the presentation.
Transactions
and balances reflecting activity between the Obligors and Non-Obligated Subsidiaries are presented below:
Amounts due from Non-Obligated Subsidiaries, current
2,268
1,927
Noncurrent
assets
78,542
69,841
Amounts due from Non-Obligated Subsidiaries, noncurrent
8,343
7,281
Current liabilities
9,240
8,005
Amounts due to Non-Obligated Subsidiaries,
current
4,624
3,477
Noncurrent liabilities
35,671
30,677
Amounts due to Non-Obligated Subsidiaries, noncurrent
20,343
13,007
Contingencies
We
are subject to legal proceedings, claims, and liabilities that arise in the ordinary course of business. We accrue for losses associated with legal claims when such losses are considered probable and the amounts can be reasonably estimated. See Note 9.
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, climate change, 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, claims of alleged environmental contamination and damages from historic operations, and climate change. 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.
Environmental
We are subject to the same numerous international,
federal, state and local environmental laws and regulations as other companies in our industry. For a discussion of the most significant of these environmental laws and regulations, including those with associated remediation obligations, see the “Environmental” section in Management’s Discussion and Analysis of Financial Condition and Results of Operations on pages 58–60 of our 2021 Annual Report on Form 10-K.
We occasionally receive requests for information or notices of potential liability from the EPA and state environmental agencies alleging that we are a potentially responsible party under the Federal Comprehensive Environmental Response, Compensation and Liability Act (CERCLA) or an equivalent state statute. On occasion, we also have been made a party to cost recovery litigation by those agencies or by private parties. These requests, notices and lawsuits assert potential liability for remediation costs at various
sites that typically are not owned by us, but allegedly contain waste attributable to our past operations. As of June 30, 2022, there were 15 sites around the U.S. in which we were identified as a potentially responsible party under CERCLA and comparable state laws.
At June 30, 2022, our balance sheet included a total environmental accrual of $178 million, compared with $187 million at December 31, 2021, for remediation activities in the U.S. and Canada. We expect to incur a substantial amount of these expenditures within the next 30 years.
Notwithstanding any of the foregoing, and as with other companies engaged in similar businesses, environmental costs and liabilities are inherent concerns in our operations and products, and there can
be no assurance that material costs and liabilities will not be incurred. However, we currently do not expect any material adverse effect upon our results of operations or financial position as a result of compliance with current environmental laws and regulations.
See Part I—Item 1A—Risk Factors – "We expect to continue to incur substantial capital expenditures and operating costs as a result of our compliance with existing and future environmental laws and regulations"in our 2021 Annual Report on Form 10-K andNote 9 for information on environmental litigation.
Climate Change
Continuing political and social attention to the issue of global climate change
has resulted in a broad range of proposed or promulgated state, national and international laws focusing on GHG reduction. These proposed or promulgated laws apply or could apply in countries where we have interests or may have interests in the future. Laws in this field continue to evolve, and while it is not possible to accurately estimate either a timetable for implementation or our future compliance costs relating to implementation, such laws, if enacted, could have a material impact on our results of operations and financial condition. For examples of legislation or precursors for possible regulation and factors on which the ultimate impact on our financial performance will depend, see the “Climate Change” section in Management’s Discussion and Analysis of Financial Condition and Results of Operations on pages 61–63 of our 2021 Annual Report on Form 10-K.
See Part I—Item 1A—Risk Factors – "Existing and future
laws, regulations and internal initiatives relating to global climate changes, such as limitations on GHG emissions may impact or limit our business plans, result in significant expenditures, promote alternative uses of energy or reduce demand for our products" in our 2021 Annual Report on Form 10-K andNote 9for information on climate change litigation.
The company has responded by putting in place a Sustainable Development Risk Management Standard covering the assessment and registration of significant and high sustainable development risks based on their consequence and likelihood of occurrence. We have developed a company-wide Climate Change Action Plan with the goal of tracking mitigation activities for each climate-related risk included in the corporate Sustainable Development Risk Register.
The risks addressed in our Climate Change Action
Plan fall into four broad categories:
•GHG-related legislation and regulation.
•GHG emissions management.
•Physical climate-related impacts.
•Climate-related disclosure and reporting.
We announced in October 2020 the adoption of a Paris-aligned climate risk framework with the objective of implementing a coherent set of choices designed to facilitate the success of our existing exploration and production business through the energy transition. Given the uncertainties remaining about how the energy transition will evolve, the strategy aims to be robust across a range of potential future outcomes.
We
announced in July 2022 that ConocoPhillips has joined the OGMP 2.0 initiative. The initiative's mission is to improve industry transparency in methane emissions reporting and encourage progress in reducing those emissions. We believe that applying the rigorous OGMP 2.0 reporting standards across our global assets will be a vital step towards meeting our Paris-aligned climate-risk commitments, including our net-zero ambition for operational emissions by 2050, and will allow us to credibly demonstrate how we are delivering against our methane improvement objectives and targets.
In 2022, we published our Plan for the Net-Zero Energy Transition (the ‘Plan’) focusing on meeting energy transition pathway demand, delivering competitive returns on and of capital and achieving our net-zero operational emissions ambitions.
Our Plan describes how we will:
•Build
a resilient asset portfolio: Focus on low cost of supply and low GHG intensity resources.
•Commit to near, medium, and long-term targets: Reducing operational (Scope 1 and 2) emissions over which we have ownership and control with an ambition to become a net-zero company for Scope 1 and 2 emissions by 2050.These targets include:
•Strengthening our previously announced operational GHG emissions intensity reduction target to 40-50% by 2030 and expanding it to apply to both a gross operated and net equity basis.
•Meeting a further 10% reduction target for methane emissions intensity by 2025 from our 2019 baseline.
•Aiming to achieve zero routine flaring
by 2025.
•Address end-use emissions: Advocate for a well-designed, economy-wide price on carbon that would help shift consumer demand from high-carbon to low-carbon energy sources.
•Pursue transition opportunities: Evaluate potential investments in emerging energy transition and low-carbon technologies.
•In 2021, we established a multi-disciplinary Low-Carbon Technologies organization to identify and evaluate business opportunities that address end-use emissions and early-stage low-carbon technology opportunities that would leverage our existing expertise and adjacencies.
•In the 2022 capital budget, we allocated $200 million to advance energy transition activities, the majority of which will address
Scope 1 and 2 emissions reduction projects across our global operations, with the rest allocated for early-stage low-carbon technology opportunities.
•Track the energy transition: Utilize a comprehensive scenario planning process to calibrate and understand alternative energy transition pathways.
•Maintain capital discipline: Use scenario analyses and a fully-burdened cost of supply, including an appropriate cost of carbon, as the primary basis for capital allocation.
Cautionary Statement for the Purposes of the “Safe Harbor” Provisions of the Private Securities Litigation Reform Act of 1995
This report includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than statements of historical fact included or incorporated by reference in this report, including, without limitation, statements regarding our future financial position, business strategy, budgets, projected revenues, projected costs and plans, objectives of management for future operations are forward-looking statements. Examples of forward-looking statements contained in this report include our expected production growth and outlook on the business environment generally,
our expected capital budget and capital expenditures, and discussions concerning future dividends. You can often identify our forward-looking statements by the words “anticipate,”“believe,”“budget,”“continue,”“could,”“effort,”“estimate,”“expect,”“forecast,”“intend,”“goal,”“guidance,”“may,”“objective,”“outlook,”“plan,”“potential,”“predict,”“projection,”“seek,”“should,”“target,”“will,”“would” and similar expressions.
We based the forward-looking statements on our current expectations, estimates and projections about ourselves and the industries in which we operate in general. We caution you these statements are not guarantees of future performance as they involve assumptions that, while made in good faith, may prove to be incorrect, and
involve risks and uncertainties we cannot predict. In addition, we based many of these forward-looking statements on assumptions about future events that may prove to be inaccurate. Accordingly, our actual outcomes and results may differ materially from what we have expressed or forecast in the forward-looking statements. Any differences could result from a variety of factors and uncertainties, including, but not limited to, the following:
•The impact of public health crises, including pandemics (such as COVID-19) and epidemics and any related company or government policies or actions.
•Global and regional changes in the demand, supply, prices, differentials or other market conditions affecting oil and gas, including changes as a result of any ongoing military conflict, including the conflict between Russia
and Ukraine, and the global response to such conflict, or from a public health crisis or from the imposition or lifting of crude oil production quotas or other actions that might be imposed by OPEC and other producing countries and the resulting company or third-party actions in response to such changes.
•Fluctuations in crude oil, bitumen, natural gas, LNG and NGLs prices, including a prolonged decline in these prices relative to historical or future expected levels.
•The impact of significant declines in prices for crude oil, bitumen, natural gas, LNG and NGLs, which may result in recognition of impairment charges on our long-lived assets, leaseholds and nonconsolidated equity investments.
•The potential for insufficient liquidity or other factors, such as those
described herein, that could impact our ability to repurchase shares and declare and pay dividends, whether fixed or variable.
•Potential failures or delays in achieving expected reserve or production levels from existing and future oil and gas developments, including due to operating hazards, drilling risks and the inherent uncertainties in predicting reserves and reservoir performance.
•Reductions in reserves replacement rates, whether as a result of the significant declines in commodity prices or otherwise.
•Unsuccessful exploratory drilling activities or the inability to obtain access to exploratory acreage.
•Unexpected changes in costs, inflationary pressures or technical requirements for constructing,
modifying or operating E&P facilities.
•Legislative and regulatory initiatives addressing environmental concerns, including initiatives addressing the impact of global climate change or further regulating hydraulic fracturing, methane emissions, flaring or water disposal.
•Lack of, or disruptions in, adequate and reliable transportation for our crude oil, bitumen, natural gas, LNG and NGLs.
•Inability to timely obtain or maintain permits, including those necessary for construction, drilling and/or development, or inability to make capital expenditures required to maintain compliance with any necessary permits or applicable laws or regulations.
•Failure to complete definitive agreements and feasibility
studies for, and to complete construction of, announced and future E&P and LNG development in a timely manner (if at all) or on budget.
•Potential
disruption or interruption of our operations due to accidents, extraordinary weather events, supply chain disruptions, civil unrest, political events, war, terrorism, cyber attacks, and information technology failures, constraints or disruptions.
•Changes in international monetary conditions and foreign currency exchange rate fluctuations.
•Changes in international trade relationships, including the imposition of trade restrictions or tariffs relating to crude oil, bitumen, natural gas, LNG, NGLs and any materials or products (such as aluminum and steel) used in the operation of our business, including any sanctions imposed as a result of any ongoing military conflict, including the conflict between Russia and Ukraine.
•Substantial investment in and development use
of, competing or alternative energy sources, including as a result of existing or future environmental rules and regulations.
•Liability for remedial actions, including removal and reclamation obligations, under existing and future environmental regulations and litigation.
•Significant operational or investment changes imposed by existing or future environmental statutes and regulations, including international agreements and national or regional legislation and regulatory measures to limit or reduce GHG emissions.
•Liability resulting from litigation, including litigation directly or indirectly related to the transaction with Concho Resources Inc., or our failure to comply with applicable laws and regulations.
•General
domestic and international economic and political developments, including armed hostilities; expropriation of assets; changes in governmental policies relating to crude oil, bitumen, natural gas, LNG and NGLs pricing; regulation or taxation; and other political, economic or diplomatic developments, including as a result of any ongoing military conflict, including the conflict between Russia and Ukraine.
•Volatility in the commodity futures markets.
•Changes in tax and other laws, regulations (including alternative energy mandates), or royalty rules applicable to our business.
•Competition and consolidation in the oil and gas E&P industry.
•Any limitations on our access to capital or increase
in our cost of capital, including as a result of illiquidity or uncertainty in domestic or international financial markets or investment sentiment.
•Our inability to execute, or delays in the completion of, any asset dispositions or acquisitions we elect to pursue.
•Potential failure to obtain, or delays in obtaining, any necessary regulatory approvals for pending or future asset dispositions or acquisitions, or that such approvals may require modification to the terms of the transactions or the operation of our remaining business.
•Potential disruption of our operations as a result of pending or future asset dispositions or acquisitions, including the diversion of management time and attention.
•Our
inability to deploy the net proceeds from any asset dispositions that are pending or that we elect to undertake in the future in the manner and timeframe we currently anticipate, if at all.
•The operation and financing of our joint ventures.
•The ability of our customers and other contractual counterparties to satisfy their obligations to us, including our ability to collect payments when due from the government of Venezuela or PDVSA.
•Our inability to realize anticipated cost savings and capital expenditure reductions.
•The inadequacy of storage capacity for our products, and ensuing curtailments, whether voluntary or involuntary, required to mitigate this physical constraint.
•The
risk that we will be unable to retain and hire key personnel.
•Unanticipated integration issues relating to the acquisition of assets from Shell, such as potential disruptions of our ongoing business and higher than anticipated integration costs.
•Uncertainty as to the long-term value of our common stock.
•The diversion of management time on integration-related matters.
•The factors generally described in Part I—Item 1A in our 2021 Annual Report on Form 10-K and any additional risks described in our other filings with the SEC.
Item 3. Quantitative and Qualitative Disclosures about Market Risk
Information about market risks for the six months ended June 30, 2022 does not differ materially from
that discussed under Item 7A in our 2021 Annual Report on Form 10-K.
Item 4. Controls and Procedures
We maintain disclosure controls and procedures designed to ensure information required to be disclosed in reports we file or submit under the Securities Exchange Act of 1934, as amended (the Act), is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms, and that such information is accumulated and communicated to management, including our principal executive and principal financial officers, as appropriate, to allow timely decisions regarding required disclosure. At June 30, 2022, with the participation of our management, our Chairman and Chief Executive Officer
(principal executive officer) and our Executive Vice President and Chief Financial Officer (principal financial officer) carried out an evaluation, pursuant to Rule 13a-15(b) of the Act, of ConocoPhillips’ disclosure controls and procedures (as defined in Rule 13a-15(e) of the Act). Based upon that evaluation, our Chairman and Chief Executive Officer and our Executive Vice President and Chief Financial Officer concluded our disclosure controls and procedures were operating effectively at June 30, 2022.
There have been no changes in our internal control over financial reporting, as defined in Rule 13a-15(f) of the Act, in the period covered by this report that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
PART
II. Other Information
Item 1. Legal Proceedings
The interim-period financial information presented in the financial statements included in this report is unaudited. There are no new material legal proceedings or material developments with respect to matters previously disclosed in Item 3 of our 2021 Annual Report on Form 10-K.
Item 1A. Risk Factors
There have been no material changes from the risk factors disclosed in Item 1A of our 2021 Annual Report on Form 10-K.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
Issuer Purchases of Equity Securities
Millions
of Dollars
Period
Total Number of
Shares
Purchased*
Average Price Paid
per Share
Total Number of
Shares Purchased as
Part of Publicly
Announced Plans or
Programs
Approximate Dollar
Value of Shares That
May Yet Be Purchased
Under
the Plans or
Programs
April 1 - 30, 2022
3,253,879
$
99.13
3,253,879
$
9,113
May 1 - 31, 2022
5,554,477
103.29
5,554,477
8,539
June
1 - 30, 2022
13,139,706
106.83
13,139,706
7,136
21,948,062
21,948,062
*There were no repurchases of common stock from company employees in connection with the company's broad-based employee incentive plans.
In late 2016, we initiated our current
share repurchase program, which has a total program authorization of $25 billion of our common stock. As of June 30, 2022, we had repurchased $17.9 billion of shares. Repurchases are made at management’s discretion, at prevailing prices, subject to market conditions and other factors. Except as limited by applicable legal requirements, repurchases may be increased, decreased or discontinued at any time without prior notice. Shares of stock repurchased under the plan are held as treasury shares. See Part I—Item 1A—Risk Factors – “Our ability to execute our capital return program is subject to certain considerations” in our 2021 Annual Report on Form 10-K.
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.