UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-Q
(Mark One)
For the quarterly period ended September 30, 2015
or
Commission File Number 001-32318
DEVON ENERGY CORPORATION
(Exact name of registrant as specified in its charter)
(State of other jurisdiction of
incorporation or organization)
(I.R.S. Employer
identification No.)
Registrant’s telephone number, including area code: (405) 235-3611
Former name, address and former fiscal year, if changed from last report: Not applicable
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No ¨
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No x
On October 21, 2015, 411.0 million shares of common stock were outstanding.
FORM 10-Q
TABLE OF CONTENTS
Part I. Financial Information
Item 1.
Consolidated Comprehensive Statements of Earnings
Consolidated Statements of Cash Flows
Consolidated Balance Sheets
Consolidated Statements of Stockholders’ Equity
Notes to Consolidated Financial Statements
Item 2.
Item 3.
Item 4.
Part II. Other Information
Item 1A.
Item 5.
Item 6.
Signatures
INFORMATION REGARDING FORWARD-LOOKING STATEMENTS
This report includes “forward-looking statements” as defined by the United States Securities and Exchange Commission (“SEC”). Such statements are those concerning strategic plans, our expectations and objectives for future operations, as well as other future events or conditions, and are often identified by use of the words “expects,” “believes,” “will,” “would,” “could,” “forecasts,” “projections,” “estimates,” “plans,” “expectations,” “targets,” “opportunities,” “potential,” “anticipates,” “outlook” and other similar terminology. Such forward-looking statements are based on our examination of historical operating trends, the information used to prepare our December 31, 2014 reserve reports and other data in our possession or available from third parties. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond our control. Consequently, actual future results could differ materially from our expectations due to a number of factors, including, but not limited to, the volatility of oil, natural gas and natural gas liquids (“NGL”) prices; uncertainties inherent in estimating oil, natural gas, and NGL reserves; changes in the supply of and demand for oil, natural gas and NGLs and related products and services; exploration or drilling programs; our ability to successfully complete mergers, acquisitions and divestitures; political or regulatory events; general economic and financial market conditions; and other risks and factors discussed in this report, our 2014 Annual Report on Form 10-K and our other filings with the SEC.
All subsequent written and oral forward-looking statements attributable to Devon Energy Corporation, or persons acting on its behalf, are expressly qualified in their entirety by the cautionary statements above. We assume no duty to update or revise our forward-looking statements based on new information, future events or otherwise.
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Item 1. Financial Statements
DEVON ENERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED COMPREHENSIVE STATEMENTS OF EARNINGS
Oil, gas and NGL sales
Oil, gas and NGL derivatives
Marketing and midstream revenues
Total operating revenues
Lease operating expenses
Marketing and midstream operating expenses
General and administrative expenses
Production and property taxes
Depreciation, depletion and amortization
Asset impairments
Restructuring costs
Gains and losses on asset sales
Other operating items
Total operating expenses
Operating income (loss)
Net financing costs
Other nonoperating items
Earnings (loss) before income taxes
Income tax expense (benefit)
Net earnings (loss)
Net earnings (loss) attributable to noncontrolling interests
Net earnings (loss) attributable to Devon
Net earnings (loss) per share attributable to Devon:
Basic
Diluted
Comprehensive earnings (loss):
Other comprehensive earnings (loss), net of tax:
Foreign currency translation
Pension and postretirement plans
Other comprehensive earnings (loss), net of tax
Comprehensive earnings (loss)
Comprehensive earnings (loss) attributable to noncontrolling interests
Comprehensive earnings (loss) attributable to Devon
See accompanying notes to consolidated financial statements.
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CONSOLIDATED STATEMENTS OF CASH FLOWS
Cash flows from operating activities:
Adjustments to reconcile net earnings (loss) to net cash from operating activities:
Deferred income tax expense (benefit)
Derivatives and other financial instruments
Cash settlements on derivatives and financial instruments
Other noncash charges
Net change in working capital
Change in long-term other assets
Change in long-term other liabilities
Net cash from operating activities
Cash flows from investing activities:
Capital expenditures
Acquisitions of property, equipment and businesses
Divestitures of property and equipment
Redemptions of long-term investments
Other
Net cash from investing activities
Cash flows from financing activities:
Borrowings of long-term debt, net of issuance costs
Repayments of long-term debt
Net short-term debt repayments
Stock option exercises
Sale of subsidiary units
Issuance of subsidiary units
Dividends paid on common stock
Distributions to noncontrolling interests
Net cash from financing activities
Effect of exchange rate changes on cash
Net change in cash and cash equivalents
Cash and cash equivalents at beginning of period
Cash and cash equivalents at end of period
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CONSOLIDATED BALANCE SHEETS
Current assets:
Cash and cash equivalents
Accounts receivable
Derivatives, at fair value
Income taxes receivable
Other current assets
Total current assets
Property and equipment, at cost:
Oil and gas, based on full cost accounting:
Subject to amortization
Not subject to amortization
Total oil and gas
Midstream and other
Total property and equipment, at cost
Less accumulated depreciation, depletion and amortization
Property and equipment, net
Goodwill
Other long-term assets
Total assets
Current liabilities:
Accounts payable
Revenues and royalties payable
Short-term debt
Deferred income taxes
Other current liabilities
Total current liabilities
Long-term debt
Asset retirement obligations
Other long-term liabilities
Stockholders’ equity:
Common stock, $0.10 par value. Authorized 1.0 billion shares; issued 411 million and 409 million shares in 2015 and 2014, respectively
Additional paid-in capital
Retained earnings
Accumulated other comprehensive earnings
Total stockholders’ equity attributable to Devon
Noncontrolling interests
Total stockholders’ equity
Commitments and contingencies (Note 17)
Total liabilities and stockholders’ equity
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CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Nine Months Ended September 30, 2015
Balance as of December 31, 2014
Net loss
Other comprehensive loss, net of tax
Restricted stock grants, net of cancellations
Common stock repurchased
Common stock retired
Common stock dividends
Share-based compensation
Subsidiary equity transactions
Balance as of September 30, 2015
Nine Months Ended September 30, 2014
Balance as of December 31, 2013
Net earnings
Share-based compensation tax benefits
Acquisition of noncontrolling interests
Balance as of September 30, 2014
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
The accompanying unaudited interim financial statements and notes of Devon Energy Corporation (“Devon,” “we,” “us” or “our”) have been prepared pursuant to the rules and regulations of the SEC. Pursuant to such rules and regulations, certain disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“U.S.”) have been omitted. The accompanying unaudited interim financial statements and notes should be read in conjunction with the financial statements and notes included in Devon’s 2014 Annual Report on Form 10-K.
The accompanying unaudited interim financial statements furnished in this report reflect all adjustments that are, in the opinion of management, necessary for a fair statement of Devon’s results of operations and cash flows for the three-month and nine-month periods ended September 30, 2015 and 2014, as applicable, and Devon’s financial position as of September 30, 2015.
Recently Issued Accounting Standards not yet Adopted
The Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, Revenue from Contracts with Customers (Topic 606). This ASU supersedes the revenue recognition requirements in Topic 605, Revenue Recognition and industry-specific guidance in Subtopic 932-605, Extractive Activities – Oil and Gas – Revenue Recognition. This ASU provides guidance concerning the recognition and measurement of revenue from contracts with customers. Its objective is to increase the usefulness of information in the financial statements regarding the nature, timing and uncertainty of revenues. The effective date for ASU 2014-09 was delayed through the issuance of ASU 2015-14, Revenue from Contracts with Customers – Deferral of the Effective Date, to annual and interim periods beginning in 2018 and is required to be adopted using either the retrospective or cumulative effect (modified retrospective) transition method, with early adoption permitted in 2017. Devon is evaluating the impact this ASU will have on its consolidated financial statements and related disclosures and does not plan on early adopting.
The FASB issued ASU 2015-02,Consolidation (Topic 810): Amendments to the Consolidation Analysis. This ASU provides additional guidance to reporting entities in evaluating whether certain legal entities, such as limited partnerships, limited liability corporations and securitization structures, should be consolidated. The ASU is considered to be an improvement on current accounting requirements as it reduces the number of existing consolidation models. The ASU is effective for annual and interim periods beginning in 2016 and is required to be adopted using a retrospective or modified retrospective approach, with early adoption permitted. Devon is evaluating the impact this ASU will have on its consolidated financial statements and related disclosures and will not early adopt.
The FASB issued ASU 2015-03, Interest – Imputation of Interest (Topic 835): Simplifying the Presentation of Debt Issuance Costs and ASU 2015-15, Interest – Imputation of Interest (Topic 835): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements. These ASUs require debt issuance costs related to a recognized debt liability, except for those related to revolving credit facilities, to be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability rather than as an asset. These ASUs are effective for annual and interim periods beginning in 2016 and are required to be applied retrospectively, with early adoption permitted. Devon does not expect the adoption to have a material impact on its consolidated financial statements and related disclosures and will not early adopt.
Acquisition of GeoSouthern and Formation of EnLink
On February 28, 2014, Devon completed its acquisition of interests in certain affiliates of GeoSouthern Energy Corporation (“GeoSouthern”). On March 7, 2014, Devon, Crosstex Energy, Inc. and Crosstex Energy, LP (together with Crosstex Energy, Inc., “Crosstex”) completed a business combination to combine substantially all of Devon’s U.S. midstream assets with Crosstex’s assets to form a new midstream business. The new business consists of EnLink Midstream, LLC (the “General Partner”) and EnLink Midstream Partners, LP (“EnLink”), which are both controlled by Devon and are publicly traded entities.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
The following unaudited pro forma financial information was prepared assuming both the GeoSouthern acquisition and the formation of EnLink and the General Partner occurred on January 1, 2014. The pro forma information has been included for comparative purposes only and is not intended to reflect the actual results of operations that would have occurred if the business combination and acquisition had been completed at the date indicated. In addition, it does not project Devon’s results of operations for any future period.
Net earnings attributable to Devon
Net earnings per common share attributable to Devon
EnLink Acquisitions
The following table presents a summary of EnLink’s acquisition activity for the first nine months of 2015.
Date
Acquiree
January 31
March 16
On October 1, 2015, EnLink acquired Delaware Basin natural gas gathering and processing assets from MRC Energy Company (“Matador”) for approximately $143 million, subject to certain adjustments.
EnLink Dropdowns
In February 2015, EnLink acquired a 25% equity interest in EnLink Midstream Holdings, LP (“EMH”) from the General Partner in exchange for units valued at approximately $925 million. In May 2015, EnLink acquired the remaining 25% equity interest in EMH from the General Partner in exchange for units valued at approximately $900 million.
In April 2015, EnLink acquired the Victoria Express Pipeline and related truck terminal and storage assets (“VEX”) from Devon for approximately $180 million in cash and equity, subject to certain adjustments. EnLink also assumed approximately $35 million in certain future construction costs to expand the system to full capacity.
Asset Divestitures
In the second quarter of 2014, Devon sold Canadian conventional assets for $2.8 billion ($3.125 billion Canadian dollars) and recognized a gain totaling $1.1 billion ($0.6 billion after-tax). This gain is included as a separate item in the accompanying consolidated comprehensive statements of earnings. Included in the gain calculation were asset retirement obligations of approximately $700 million assumed by the purchaser as well as the derecognition of approximately $700 million of goodwill allocated to the sold assets. In conjunction with the divestiture, Devon repatriated approximately $2.8 billion of proceeds to the U.S.
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in the second quarter of 2014, which was utilized to repay commercial paper and term loan balances. Between collecting the divestiture proceeds and repatriating funds to the U.S., Devon recognized an $84 million foreign currency exchange loss and a $29 million foreign currency derivative loss. These losses are included in other nonoperating items in the accompanying consolidated comprehensive statements of earnings.
In the third quarter of 2014, Devon sold certain U.S. assets for $2.2 billion. Additionally, approximately $200 million of asset retirement obligations were assumed by the purchaser. No gain or loss was recognized on the sale.
Objectives and Strategies
Devon periodically enters into derivative financial instruments with respect to a portion of its oil, gas and NGL production to hedge future prices received. Additionally, Devon and EnLink periodically enter into derivative financial instruments with respect to a portion of their oil, gas and NGL marketing activities. These commodity derivative financial instruments include financial price swaps, basis swaps, costless price collars and call options. Devon periodically enters into interest rate swaps to manage its exposure to interest rate volatility and foreign exchange forward contracts to manage its exposure to fluctuations in the U.S. and Canadian dollar exchange rates.
Devon does not intend to hold or issue derivative financial instruments for speculative trading purposes and has elected not to designate any of its derivative instruments for hedge accounting treatment.
Counterparty Credit Risk
By using derivative financial instruments, Devon is exposed to credit risk. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. To mitigate this risk, the hedging instruments are placed with a number of counterparties whom Devon believes are acceptable credit risks. It is Devon’s policy to enter into derivative contracts only with investment-grade rated counterparties deemed by management to be competent and competitive market makers. Additionally, Devon’s derivative contracts contain provisions that provide for collateral payments, depending on levels of exposure and the credit rating of the counterparty.
As of September 30, 2015 and December 31, 2014, Devon held $169 million and $524 million, respectively, of cash collateral which represented the estimated fair value of certain derivative positions in excess of Devon’s credit guidelines. The collateral is reported in other current liabilities in the accompanying consolidated balance sheets.
Commodity Derivatives
As of September 30, 2015, Devon had the following open oil derivative positions. The first table presents Devon’s oil derivatives that settle against the average of the prompt month NYMEX West Texas Intermediate (“WTI”) futures price. The second table presents Devon’s oil derivatives that settle against the respective indices noted within the table.
Period
Q4 2015
Q1-Q4 2016
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Oil Basis Swaps
Index
As of September 30, 2015, Devon had the following open natural gas derivative positions. The first table presents Devon’s natural gas derivatives that settle against the Inside FERC first of the month Henry Hub index. The second table presents Devon’s natural gas derivatives that settle against the respective indices noted within the table.
Natural Gas Basis Swaps
Q1-Q4 2017
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As of September 30, 2015, EnLink had the following open derivative positions associated with gas processing and fractionation. EnLink’s NGL derivative positions settle by purity product against the average of the prompt month OPIS Mont Belvieu, Texas index. EnLink’s natural gas derivative positions settle against the Henry Hub Gas Daily index.
Product
Q4 2015-Q4 2016
Q4 2015-Q3 2016
Interest Rate Derivatives
As of September 30, 2015, Devon had the following open interest rate derivative positions:
Notional
Rate Received
Rate Paid
Expiration
Foreign Currency Derivatives
As of September 30, 2015, Devon had the following open foreign currency derivative position:
Forward Contract
Currency
Contract Type
Weighted Average Fixed RateReceived
Canadian Dollar
Financial Statement Presentation
The following table presents the net gains and losses by derivative financial instrument type followed by the corresponding individual comprehensive statements of earnings caption.
Commodity derivatives:
Interest rate derivatives:
Foreign currency derivatives:
Net gains recognized
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The following table presents the derivative fair values by derivative financial instrument type followed by the corresponding individual consolidated balance sheet caption.
Commodity derivative assets:
Interest rate derivative assets:
Foreign currency derivative assets:
Total derivative assets
Commodity derivative liabilities:
Interest rate derivative liabilities:
Total derivative liabilities
The following table presents the effects of share-based compensation included in Devon’s accompanying consolidated comprehensive statements of earnings. Devon’s gross general and administrative expense for the first nine months of 2015 and 2014 includes $25 million and $11 million, respectively, of unit-based compensation related to grants made under EnLink’s long-term incentive plans.
The vesting for certain share-based awards was accelerated in 2014 in conjunction with the divestiture of Devon’s Canadian conventional assets. For the nine months ended September 30, 2014, approximately $15 million of associated expense for these accelerated awards is included in restructuring costs in the accompanying consolidated comprehensive statements of earnings.
Gross general and administrative expense for share-based compensation
Share-based compensation expense capitalized pursuant to the full cost method of accounting for oil and gas properties
Related income tax benefit
12
Under its 2009 Long-Term Incentive Plan, as amended (the “2009 Plan”), and its 2015 Long-Term Incentive Plan (the “2015 Plan”), Devon granted share-based awards to certain employees and directors in the first nine months of 2015. The following table presents a summary of Devon’s unvested restricted stock awards and units, performance-based restricted stock awards and performance share units granted under the plans.
Unvested at 12/31/14
Granted
Vested
Forfeited
Unvested at 9/30/15
The following table presents the assumptions related to the performance share units granted in 2015, as indicated in the previous summary table.
Grant-date fair value
Risk-free interest rate
Volatility factor
Contractual term (years)
The following table presents a summary of the unrecognized compensation cost and the related weighted average recognition period associated with unvested awards and units.
Unrecognized compensation cost (millions)
Weighted average period for recognition (years)
13
2015 Long-Term Incentive Plan
In the second quarter of 2015, Devon’s stockholders approved the 2015 Plan. The 2015 Plan replaces the 2009 Plan. From the effective date of the 2015 Plan, no further awards may be made under the 2009 Plan, and awards previously granted will continue to be governed by the terms of the 2009 Plan. Subject to the terms of the 2015 Plan, awards may be made under the 2015 Plan for a total of 28 million shares of Devon common stock, plus the number of shares available for issuance under the 2009 Plan (including shares subject to outstanding awards under the 2009 Plan that are subsequently forfeited, cancelled or expire). The 2015 Plan authorizes the Compensation Committee, which consists of independent, non-management members of Devon’s Board of Directors, to grant nonqualified and incentive stock options, restricted stock awards or units, Canadian restricted stock units, performance awards or units and stock appreciation rights to eligible employees. The 2015 Plan also authorizes the grant of nonqualified stock options, restricted stock awards or units and stock appreciation rights to non-employee directors. To calculate the number of shares that may be granted in awards under the 2015 Plan, options and stock appreciation rights represent one share and other awards represent three shares.
EnLink Share-Based Awards
In March 2015, the General Partner and EnLink issued restricted incentive units as bonus payments to officers and certain employees for 2014. The combined grant fair value was $7 million, and the total cost was recognized in the first quarter of 2015 due to the awards vesting immediately.
The following table presents a summary of the unrecognized compensation cost and the related weighted average recognition period associated with the General Partner’s and EnLink’s unvested restricted incentive units and performance units.
The following table presents the asset impairments recognized by Devon in the first nine months of 2015.
U.S. oil and gas assets
Canada oil and gas assets
EnLink goodwill
EnLink other intangible assets
Other assets
Total asset impairments
Oil and Gas Impairments
Under the full cost method of accounting, capitalized costs of oil and gas properties, net of accumulated DD&A and deferred income taxes, may not exceed the full cost “ceiling” at the end of each quarter. The ceiling is calculated separately for each country and is based on the present value of estimated future net cash flows from proved oil and gas reserves, discounted at 10% per annum, net of related tax effects. Estimated future net cash flows are calculated using end-of-period costs and an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous 12 months.
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The oil and gas impairments resulted from declines in the U.S. and Canada full cost ceilings. The lower ceiling values resulted primarily from significant decreases in the 12-month average trailing prices for oil, bitumen, gas and NGLs, which significantly reduced proved reserves values and, to a lesser degree, proved reserves.
EnLink Goodwill and Other Intangible Assets Impairments
In the third quarter of 2015, Devon recognized goodwill and other intangible assets impairments related to EnLink’s business. Additional information regarding the impairments is discussed in Note 11.
The following table presents Devon’s total income tax expense (benefit) and a reconciliation of its effective income tax rate to the U.S. statutory income tax rate.
Total income tax expense (benefit) (millions)
U.S. statutory income tax rate
Non-deductible goodwill and intangible impairment
Taxation on Canadian operations
State income taxes
Repatriations
Effective income tax rate
Devon estimates its annual effective income tax rate in recording its quarterly provision for income taxes in the various jurisdictions in which it operates. Statutory tax rate changes and other significant or unusual items are recognized as discrete items in the quarter in which they occur.
In the third quarter of 2015, EnLink recorded goodwill and intangibles impairments of approximately $799 million. These impairments are not deductible for purposes of calculating income tax and therefore have an impact on the effective tax rate.
In the second quarter of 2015, Devon recognized $57 million of income tax benefits in conjunction with favorable tax settlements. In addition, changes in statutory tax rates in Texas and the province of Alberta, Canada resulted in a net increase to deferred tax expense of $44 million.
Devon and its subsidiaries are subject to U.S. federal income tax as well as income or capital taxes in various state and foreign jurisdictions. Devon’s tax reserves are related to tax years that may be subject to examination by the relevant taxing authority. Devon is under audit in the U.S. and various foreign jurisdictions as part of its normal course of business.
In the third quarter of 2014, Devon completed its U.S. asset divestiture program. In conjunction with the divestiture closing, Devon recognized $543 million of current income tax expense. The current tax expense was entirely offset by the recognition of deferred tax benefits.
In the second quarter of 2014, Devon recognized $247 million of additional income tax expense related to the $2.8 billion of repatriations to the U.S. Prior to the repatriation, Devon had recognized a $143 million deferred income tax liability associated with the planned repatriation. When the repatriation was made, Devon retained a larger property basis in Canada than was previously estimated, resulting in the incremental tax in the second quarter.
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The following table reconciles net earnings (loss) attributable to Devon and common shares outstanding used in the calculations of basic and diluted net earnings per share.
Net earnings (loss):
Attributable to participating securities
Basic and diluted earnings (loss)
Common shares:
Common shares outstanding - total
Common shares outstanding - basic
Dilutive effect of potential common shares issuable
Common shares outstanding - diluted
Antidilutive options (1)
Components of other comprehensive earnings consist of the following:
Foreign currency translation:
Beginning accumulated foreign currency translation
Change in cumulative translation adjustment
Income tax benefit
Ending accumulated foreign currency translation
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Pension and postretirement benefit plans:
Beginning accumulated pension and postretirement benefits
Recognition of net actuarial loss and prior service cost in earnings(1)
Income tax expense
Ending accumulated pension and postretirement benefits
Accumulated other comprehensive earnings, net of tax
Net change in working capital accounts:
Income taxes payable
Interest paid (net of capitalized interest)
Income taxes paid (received)
On March 7, 2014, Devon completed a business combination to form EnLink. With the exception of a $100 million cash payment to noncontrolling interests, the business combination was a non-monetary transaction. Furthermore, EnLink’s noncash acquisition activity during the first nine months of 2015 included a portion of the Coronado transaction. See Note 2 for additional details.
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Components of accounts receivable include the following:
Joint interest billings
Gross accounts receivable
Allowance for doubtful accounts
Net accounts receivable
The following table presents a summary of Devon’s goodwill.
Acquired during period
Impairment
See Note 2 for discussion of changes in goodwill resulting from acquisitions during the first nine months of 2015.
Devon performs an annual impairment test of goodwill at October 31, or more frequently if events or changes in circumstances indicate that the carrying value of a reporting unit may not be recoverable. Sustained weakness in the overall energy sector driven by low commodity prices, together with a decline in EnLink’s unit price, caused a change in circumstances warranting an interim impairment test of EnLink’s reporting units. In the third quarter of 2015, Devon recorded a noncash goodwill impairment of $576 million related to EnLink’s Louisiana reporting unit.
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Other Intangible Assets
The assessment of EnLink’s customer relationships was also updated as of September 30, 2015 due to the factors in the aforementioned goodwill impairment analysis. Level 3 fair value measurements were utilized for the impairment analysis of definite-lived intangible assets, which included discounted cash flow estimates, consistent with those utilized in the goodwill impairment assessment. This assessment resulted in Devon recognizing a $223 million noncash other intangible assets impairment related to EnLink’s Crude and Condensate reporting unit.
The following table presents other intangible assets reported in other long-term assets in the accompanying consolidated balance sheets.
Customer relationships
Accumulated amortization
Net intangibles
The weighted-average amortization period for other intangible assets is 11.4 years. Amortization expense for intangibles was approximately $14.6 million and $10.2 million for the three months ended September 30, 2015 and 2014, respectively, and $44.3 million and $23.2 million for the nine months ended September 30, 2015 and 2014, respectively.
The following table presents a summary of the estimated remaining aggregate amortization expense for the next five years.
Year
2015
2016
2017
2018
2019
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A summary of debt is as follows:
Devon debt
Commercial paper
Floating rate due December 15, 2015
Floating rate due December 15, 2016
8.25% due July 1, 2018
2.25% due December 15, 2018
6.30% due January 15, 2019
4.00% due July 15, 2021
3.25% due May 15, 2022
7.50% due September 15, 2027
7.875% due September 30, 2031
7.95% due April 15, 2032
5.60% due July 15, 2041
4.75% due May 15, 2042
5.00% due June 15, 2045
Net discount on debentures and notes
Total Devon debt
EnLink debt
Credit facilities
2.70% due April 1, 2019
7.125% due June 1, 2022
4.40% due April 1, 2024
4.15% due June 1, 2025
5.60% due April 1, 2044
5.05% due April 1, 2045
Net premium on debentures and notes
Total EnLink debt
Total debt
Less amount classified as short-term debt (1)
Total long-term debt
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Long-Term Debt
In June 2015, Devon issued $750 million of 5.0% senior notes that are unsecured and unsubordinated obligations. Devon intends to use the net proceeds to repay the aggregate principal amount of the floating rate senior notes due 2015 when they mature on December 15, 2015. Pending that use, part of the net proceeds have been used to repay a portion of outstanding commercial paper balances.
Commercial Paper
During the nine months ended September 30, 2015, Devon reduced commercial paper borrowings by $932 million. As of September 30, 2015, Devon had no outstanding commercial paper borrowings.
Credit Lines
Devon has a $3.0 billion syndicated, unsecured revolving line of credit (the “Senior Credit Facility”). As of September 30, 2015, there were no borrowings under the Senior Credit Facility. The Senior Credit Facility contains only one material financial covenant. This covenant requires Devon’s ratio of total funded debt to total capitalization, as defined in the credit agreement, to be no greater than 65%. Under the terms of the credit agreement, total capitalization is adjusted to add back noncash financial write-downs such as full cost ceiling impairments or goodwill impairments. As of September 30, 2015, Devon was in compliance with this covenant with a debt-to-capitalization ratio of 21.9%.
EnLink Debt
All of EnLink’s and the General Partner’s debt is non-recourse to Devon.
EnLink has a $1.5 billion unsecured revolving credit facility. As of September 30, 2015, there were $2.8 million in outstanding letters of credit and $175 million in outstanding borrowings at an average rate of 1.46% under the $1.5 billion credit facility. The General Partner has a $250 million secured revolving credit facility. As of September 30, 2015, the General Partner had no outstanding borrowings under the $250 million credit facility. EnLink and the General Partner were in compliance with all financial covenants in their respective credit facilities as of September 30, 2015.
In May 2015, EnLink issued $900 million principal amount of unsecured senior notes, consisting of $750 million principal amount of its 4.15% senior notes due 2025 and an additional $150 million principal amount of its 5.05% senior notes due 2045. EnLink used the net proceeds to repay outstanding borrowings under its revolving credit facility, for capital expenditures and for general operations.
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The following table presents the changes in Devon’s asset retirement obligations.
Asset retirement obligations as of beginning of period
Liabilities incurred
Liabilities settled and divested (1)
Revision of estimated obligation
Accretion expense on discounted obligation
Foreign currency translation adjustment
Asset retirement obligations as of end of period
Less current portion
Asset retirement obligations, long-term
The following table presents the components of net periodic benefit cost for Devon’s pension and postretirement benefit plans.
Service cost
Interest cost
Expected return on plan assets
Amortization of prior service cost (1)
Net actuarial loss (gain) (1)
Net periodic benefit cost (2)
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Dividends
Devon paid common stock dividends of $296 million and $287 million in the first nine months of 2015 and 2014, respectively. Devon increased the quarterly cash dividend rate from $0.22 per share to $0.24 per share in the second quarter of 2014.
Stock Option Proceeds
Devon received $4 million and $92 million from stock option proceeds during the first nine months of 2015 and 2014, respectively.
Subsidiary Equity Transactions
In March 2015, Devon conducted an underwritten secondary public offering of 22.8 million common units representing limited partner interests in EnLink, raising net proceeds of $569 million. In April 2015, as part of the secondary public offering, the underwriters fully exercised their option to purchase an additional 3.4 million EnLink common units from Devon, resulting in an incremental $85 million of net proceeds raised.
Through its equity distribution agreements, EnLink has the ability to sell common units through an “at the market” equity offering program. During the first nine months of 2015 and 2014, EnLink sold approximately 0.7 million and 2.4 million common units, generating net proceeds of $13 million and $72 million, respectively.
As a result of these transactions and the Coronado acquisition and dropdown transactions discussed in Note 2, Devon’s ownership interest in EnLink decreased from 49% at December 31, 2014 to 29% at September 30, 2015, excluding the interest held by the General Partner. The net gains and losses and related income taxes resulting from these transactions have been recorded as an adjustment to equity, and the change in ownership reflected as an adjustment to noncontrolling interests.
On October 29, 2015, the General Partner acquired approximately 2.8 million common units in EnLink in a private placement. EnLink received proceeds of $50 million in the transaction.
Distributions to Noncontrolling Interests
EnLink and the General Partner distributed $186 million and $187 million to non-Devon unitholders during the first nine months of 2015 and 2014, respectively.
Devon is party to various legal actions arising in the normal course of business. Matters that are probable of unfavorable outcome to Devon and which can be reasonably estimated are accrued. Such accruals are based on information known about the matters, Devon’s estimates of the outcomes of such matters and its experience in contesting, litigating and settling similar matters. None of the actions are believed by management to involve future amounts that would be material to Devon’s financial position or results of operations after consideration of recorded accruals. Actual amounts could differ materially from management’s estimates.
Royalty Matters
Numerous oil and natural gas producers and related parties, including Devon, have been named in various lawsuits alleging royalty underpayments. The suits allege that the producers and related parties used below-market prices, made improper deductions, used improper measurement techniques and entered into gas purchase and processing arrangements with affiliates that resulted in underpayment of royalties in connection with oil, natural gas and NGLs produced and sold. Devon is also involved in governmental agency proceedings and is subject to related contracts and regulatory controls in the ordinary course of business, some that may lead to additional royalty claims. Devon does not currently believe that it is subject to material exposure with respect to such royalty matters.
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Environmental Matters
Devon is subject to certain laws and regulations relating to environmental remediation activities associated with past operations, such as the Comprehensive Environmental Response, Compensation, and Liability Act and similar state statutes. In response to liabilities associated with these activities, loss accruals primarily consist of estimated uninsured remediation costs. Devon’s monetary exposure for environmental matters is not expected to be material.
Other Matters
Devon is involved in other various routine legal proceedings incidental to its business. However, to Devon’s knowledge, there were no other material pending legal proceedings to which Devon is a party or to which any of its property is subject.
The following table provides carrying value and fair value measurement information for certain of Devon’s financial assets and liabilities. The carrying values of cash, accounts receivable, other current receivables, accounts payable, other current payables and accrued expenses included in the accompanying consolidated balance sheets approximated fair value at September 30, 2015 and December 31, 2014. Therefore, such financial assets and liabilities are not presented in the following tables. Additionally, information regarding the fair values of oil and gas assets, goodwill and other intangible assets is provided in Note 5 and Note 11.
September 30, 2015 assets (liabilities):
Cash equivalents
Commodity derivatives
Interest rate derivatives
Foreign currency derivatives
Debt
Capital lease obligations
December 31, 2014 assets (liabilities):
The following methods and assumptions were used to estimate the fair values in the table above.
Level 1 Fair Value Measurements
Cash equivalents – Amounts consist primarily of money market investments. The fair value approximates the carrying value.
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Level 2 Fair Value Measurements
Cash equivalents – Amounts consist primarily of commercial paper and Canadian agency and provincial securities investments. The fair value approximates the carrying value.
Commodity, interest rate and foreign currency derivatives – The fair values of commodity, interest rate and foreign currency derivatives are estimated using internal discounted cash flow calculations based upon forward curves and data obtained from independent third parties for contracts with similar terms or data obtained from counterparties to the agreements.
Debt – Devon’s debt instruments do not actively trade in an established market. The fair values of its debt are estimated based on rates available for debt with similar terms and maturity. The fair values of commercial paper and credit facility balances are the carrying values.
Capital lease obligations – The fair value was calculated using inputs from third-party banks.
Devon manages its operations through distinct operating segments, which are defined primarily by geographic areas. For financial reporting purposes, Devon aggregates its U.S. exploration and production operating segments into one reporting segment due to the similar nature of the businesses. However, Devon’s Canadian exploration and production operating segment is reported as a separate reporting segment primarily due to the significant differences between the U.S. and Canadian regulatory environments. Devon’s U.S. and Canadian segments are both primarily engaged in oil and gas exploration and production activities.
EnLink, combined with the General Partner, is presented as a separate reporting segment. Devon considers EnLink’s operations distinct from the U.S. and Canadian operating segments. Additionally, EnLink has a management team that is primarily responsible for capital and resource allocation decisions.
Three Months Ended September 30, 2015:
Revenues from external customers
Intersegment revenues
Interest expense
Loss before income taxes
Net loss attributable to noncontrolling interests
Net loss attributable to Devon
Three Months Ended September 30, 2014:
Earnings before income taxes
Net earnings attributable to noncontrolling interests
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Nine Months Ended September 30, 2015:
Nine Months Ended September 30, 2014:
Year Ended December 31, 2014:
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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion and analysis addresses material changes in our results of operations and capital resources and uses for the three-month and nine-month periods ended September 30, 2015, compared to the three-month and nine-month periods ended September 30, 2014 and in our financial condition and liquidity since December 31, 2014. For information regarding our critical accounting policies and estimates, see our 2014 Annual Report on Form 10-K under “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.”
Overview of 2015 Results
Key components of our financial performance are summarized below.
Core earnings attributable to Devon(1)
Earnings (loss) per share attributable to Devon
Core earnings per share attributable to Devon (1)
Retained production (MBoe/d)
Total production (MBoe/d)
Realized price per Boe
Operating cash flow
Capitalized costs, including acquisitions
Shareholder and noncontrolling interests distributions
The downward pressure on crude oil prices that began in November 2014 has continued throughout 2015. As compared to the third quarter and first nine months of 2014, the 2015 WTI crude oil index decreased roughly 50%, and the Henry Hub natural gas index dropped roughly one third. Additionally, NGL prices have also been challenged. As a result, net earnings attributable to Devon, core earnings attributable to Devon and core earnings per share attributable to Devon for the third quarter and first nine months of 2015 decreased significantly compared to the same periods in 2014.
Although we are operating in a challenging environment, we believe that we have strategically positioned our company so that we can prudently continue investing in our portfolio of assets in 2015 and remain in a financially strong position, as detailed below:
In the third quarter of 2015, we recognized $5.9 billion of asset impairments related to the depressed prices for commodities. While these impairments significantly impacted our earnings, they had no effect on our operating cash flow, which funded all our capital requirements in the third quarter of 2015.
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As we look forward to the fourth quarter of 2015 and into 2016, we expect commodity pricing to continue to be challenged. A sustained low commodity price environment, coupled with a significant portion of our hedges expiring in the fourth quarter of 2015, will impact net earnings attributable to Devon, core earnings attributable to Devon and core earnings per share attributable to Devon.
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Results of Operations
Oil, Gas and NGL Production
Oil (MBbls/d)
Anadarko Basin
Barnett Shale
Delaware Basin
Eagle Ford
Midland Basin
Rockies
Total U.S.
Canada
Total retained properties
Divested properties
Total
Bitumen (MBbls/d)
Gas (MMcf/d)
NGLs (MBbls/d)
Combined (MBoe/d)
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Oil, Gas and NGL Pricing
Oil (per Bbl)
U.S.
Bitumen (per Bbl)
Gas (per Mcf)
Canada (2)
NGLs (per Bbl)
Combined (per Boe)
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Commodity Sales
The volume and price changes in the tables above caused the following changes to our oil, gas and NGL sales between the three and nine months ended September 30, 2015 and 2014.
2014 sales
Change due to volumes
Change due to prices
2015 sales
Oil, gas and NGL sales increased in the third quarter and first nine months of 2015 due to strong production growth from our U.S. oil properties. The growth was primarily driven by the continued development of our Eagle Ford, Delaware Basin and Rockies properties. Additionally, our bitumen production increased in both periods, primarily due to Jackfish 3 coming on-line late in the third quarter of 2014 and reaching nameplate capacity in the third quarter of 2015. Lower royalties resulting from the significant price decrease also increased our heavy oil production. The increases were partially offset by a decrease in our gas production, which resulted primarily from asset divestitures in 2014.
Oil, gas and NGL sales decreased in the third quarter and first nine months of 2015 due to significant price decreases for all commodities. The decrease in oil and bitumen sales resulted from lower average WTI crude oil index prices, which were 52% lower than the third quarter of 2014 and 49% lower than the first nine months of 2014. The decreases in gas and NGL sales for both periods were due to lower North American regional index prices upon which our gas sales are based and lower NGL prices at the Mont Belvieu, Texas hub.
Oil, Gas and NGL Derivatives
A summary of our open commodity derivative positions is included in Note 3 to the financial statements included in “Part 1. Financial Information – Item 1. Financial Statements” of this report. The following tables provide financial information associated with our commodity derivatives. The first table presents the cash settlements and fair value gains and losses recognized as components of our revenues. The subsequent tables present our oil, bitumen, gas and NGL prices with, and without, the effects of the cash settlements. The prices do not include the effects of fair value gains and losses.
Cash settlements:
Oil derivatives
Gas derivatives
Total cash settlements
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Gains (losses) on fair value changes:
Total gains (losses) on fair value changes
Realized price without hedges
Cash settlements of hedges (1)
Realized price, including cash settlements
Cash settlements as presented in the tables above represent realized gains or losses related to various commodity derivatives. In addition to cash settlements, we also recognize fair value changes on our commodity derivatives in each reporting period. The changes in fair value result from new positions and settlements that occur during each period, as well as the relationships between contract prices and the associated forward curves. Including the cash settlements discussed above, our commodity derivatives generated net gains in all periods presented.
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Marketing and Midstream Revenues and Operating Expenses
Operating revenues
Product purchases
Operations and maintenance expenses
Operating profit
Devon profit
EnLink profit
Total profit
Marketing and midstream operating profit changes were largely driven by EnLink’s acquisitions in the fourth quarter of 2014 and first nine months of 2015, partially offset by a decrease in Devon’s marketing activities due to a decrease in commodity prices.
Lease Operating Expenses (“LOE”)
LOE:
LOE per Boe:
LOE per Boe decreased during the third quarter and the first nine months of 2015 primarily due to higher Jackfish 3 volumes, our cost reduction initiatives, lower royalties and changes in the Canadian to U.S. foreign exchange rate. As Canadian royalties decrease, our net production volumes increase, causing improvements to our per-unit operating costs. For the first nine months of 2015, the impact of our Canadian decrease to total unit costs was partially offset by higher unit costs in the U.S. The slightly higher U.S. rate is primarily related to our 2014 gas asset divestitures and our oil production growth, where projects generate higher margins but generally require a higher cost to produce per unit than our retained and divested gas projects.
General and Administrative Expenses (“G&A”)
Gross G&A
Capitalized G&A
Reimbursed G&A
Net G&A
Net G&A per Boe
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Gross G&A, net G&A and net G&A per Boe increased during the first nine months of 2015 largely due to an increase in EnLink G&A of approximately $39 million combined with higher Devon employee costs in the first quarter of 2015. As a result of our cost reduction initiatives, gross G&A has declined approximately 8% in the second quarter compared to the first quarter of 2015 and has declined 8% in the third quarter compared to the second quarter of 2015. Net G&A also increased from lower reimbursements subsequent to our 2014 asset divestitures. These increases were partially offset by $22 million in one-time costs related to the EnLink and GeoSouthern transactions in the first quarter of 2014.
Production and Property Taxes
Production
Property and other
Percentage of oil, gas and NGL sales:
Our absolute production and property taxes decreased during the third quarter and first nine months of 2015 primarily due to a decrease in our U.S. revenues, on which the majority of our production taxes are assessed. Production and property taxes as a percentage of oil, gas and NGL sales increased during the third quarter and first nine months of 2015 primarily due to ad valorem and other taxes that do not change in direct correlation with oil, gas and NGL sales.
Depreciation, Depletion and Amortization (“DD&A”)
DD&A:
Oil & gas properties
DD&A per Boe:
DD&A from our oil and gas properties decreased in the third quarter of 2015 compared to the third quarter of 2014 largely due to lower DD&A rates, as a result of the oil and gas asset impairments recognized in the first and second quarters of 2015.
DD&A from our oil and gas properties decreased for the first nine months of 2015 compared to the first nine months of 2014 largely due to the 2014 divestitures of certain U.S. and Canadian assets and the oil and gas asset impairments recognized in the first and second quarters of 2015. This decrease was partially offset by higher DD&A rates resulting from our oil and gas drilling and development activities and the 2014 GeoSouthern acquisition. Other DD&A increased primarily due to EnLink’s acquisitions
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in 2014 and the first nine months of 2015 and drove the overall increase in DD&A for the first nine months of 2015.
Asset Impairments
During the third quarter and first nine months of 2015, we recognized asset impairments of $5.9 billion and $15.5 billion, respectively. For further discussion, see Note 5 in “Part 1. Financial Information – Item 1. Financial Statements.”
Gain on Asset Sales
In conjunction with the divestiture of certain Canadian properties, we recognized a gain of $1.1 billion in the first nine months of 2014. For further discussion, see Note 2 in “Part 1. Financial Information – Item 1. Financial Statements.”
Net Financing Costs
Interest based on debt outstanding
Capitalized interest
Other fees and expenses
Interest income
Net financing costs increased during the third quarter of 2015 primarily due to an increase in EnLink fixed-rate borrowings. Net financing costs increased during the first nine months of 2015 primarily due to an increase of $38 million in EnLink interest expense as a result of an increase in fixed-rate borrowings partially offset by a $25 million decline in Devon interest expense as a result of a decrease in fixed-rate borrowings.
Income Taxes
For further discussion of our income tax expense (benefit), see Note 6 in “Part 1. Financial Information – Item 1. Financial Statements.”
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Capital Resources, Uses and Liquidity
Sources and Uses of Cash
The following table presents the major changes in our cash and cash equivalents for the nine months ended September 30, 2015 and 2014.
Debt activity, net
EnLink and General Partner distributions
EnLink dropdowns
Stock option proceeds
Effect of exchange rate and other
Operating Cash Flow
Net cash provided by operating activities (“operating cash flow”) was a significant source of capital in the first nine months of 2015. Our consolidated operating cash flow decreased 14% primarily due to lower commodity prices. The effect of lower prices was partially offset by the collection of $425 million of income taxes receivable in the first quarter of 2015 and cash settlements associated with our commodity derivatives during the first nine months of 2015.
Excluding payments made for acquisitions, our consolidated operating cash flow funded 100% of our capital expenditures during the first nine months of 2015 and 2014. In 2015, leveraging our liquidity, we also used cash balances, short-term debt and proceeds from the sale of EnLink common units to help fund our acquisitions and other operating needs.
Sale of Subsidiary Units
In March 2015, we conducted an underwritten secondary public offering of 22.8 million common units representing limited partner interests in EnLink, raising proceeds of $569 million, net of underwriting discount. Additionally, in April 2015, as part of the secondary public offering, underwriters fully exercised their option to purchase an additional 3.4 million EnLink common units from Devon, resulting in an incremental $85 million of net proceeds raised.
Divestitures of Property and Equipment
In the first nine months of 2014, we sold certain Canadian and U.S. assets as part of our 2014 asset divestiture program. For further discussion, see Note 2 in “Part 1. Financial Information – Item 1. Financial Statements.”
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Capital Expenditures and Acquisitions of Property, Equipment and Businesses
The amounts in the table below reflect cash payments for capital expenditures, including cash paid for capital expenditures incurred in prior periods.
Exploration and development
Acquisition of oil and gas properties
Capitalized G&A and interest
Midstream
Corporate and other
Devon capital expenditures
EnLink, including acquisitions
Total capital expenditures
Capital expenditures consist of amounts related to our oil and gas exploration and development operations, midstream operations, other corporate activities and EnLink growth and maintenance activities. The vast majority of Devon’s capital expenditures are for the acquisition, drilling and development of oil and gas properties. In response to lower commodity prices, Devon’s 2015 capital program is designed to be lower than 2014, particularly compared to the second half of 2014 when oil prices began to significantly decline. This change is evidenced by a 46% decrease in exploration and development costs from the fourth quarter of 2014 to the third quarter of 2015 as well as a 24% decrease from the second quarter of 2015 to the third quarter of 2015.
Capital expenditures for Devon’s midstream operations are primarily for the construction and expansion of oil and gas gathering facilities and pipelines. Midstream capital expenditures are largely impacted by Devon’s oil and gas drilling activities. EnLink’s expenditures were primarily related to the acquisition of additional oil and gas pipeline assets.
Debt Activity, Net
In 2015, our consolidated net debt borrowings increased $623 million. In June 2015, we issued $750 million of 5.0% senior notes that are unsecured and unsubordinated obligations of Devon. We intend to use these proceeds to repay the aggregate principal amount of our floating rate senior notes when they mature on December 15, 2015. Pending that use, part of these proceeds have been used to repay a portion of outstanding commercial paper balances. EnLink’s net debt borrowings increased $821 million primarily due to borrowings made to fund acquisitions and dropdowns.
In 2014, our consolidated net debt borrowings decreased $1.4 billion. The decrease was the net impact of repaying our $500 million senior notes upon maturity and reducing commercial paper balances by $1.3 billion primarily with repatriated Canadian divestiture proceeds, which were offset by EnLink borrowings of $400 million.
Shareholder and Noncontrolling Interests Distributions
The following table summarizes our common stock dividends during the first nine months of 2015 and 2014. In the second quarter of 2014, we increased our quarterly dividend to $0.24 per share.
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EnLink and General Partner Distributions
Devon received $202 million and $57 million in distributions from EnLink and the General Partner during the first nine months of 2015 and 2014, respectively.
In the second quarter of 2015, Devon received $171 million in cash from EnLink in exchange for VEX. For further discussion, see Note 2 in “Part 1. Financial Information – Item 1. Financial Statements.”
We received $4 million and $92 million from stock option proceeds during the first nine months of 2015 and 2014, respectively.
Issuance of Subsidiary Units
During the first nine months of 2015 and 2014, EnLink sold approximately 0.7 million and 2.4 million common units through its “at the market” equity program, generating net proceeds of $13 million and $72 million, respectively.
Liquidity
Historically, our primary sources of capital and liquidity have been our operating cash flow and cash on hand. Additionally, we maintain a commercial paper program, supported by our revolving line of credit, which can be accessed as needed to supplement operating cash flow and cash balances. Other available sources of capital and liquidity include, among other things, debt and equity securities that can be issued pursuant to our shelf registration statement filed with the SEC, as well as the sale of a portion of our common units representing interests in our investment in EnLink and the General Partner and asset dropdowns to EnLink in exchange for cash. We estimate the combination of these sources of capital will continue to be adequate to fund future capital expenditures, debt repayments and other contractual commitments.
Our operating cash flow is sensitive to many variables, the most volatile of which are the prices of the oil, bitumen, gas and NGLs we produce and sell. Our consolidated operating cash flow decreased 14% in the first nine months of 2015 compared to the first nine months of 2014 as a result of the significant decrease in commodity prices. In spite of this decline, we expect operating cash flow to continue to be our primary source of liquidity as we adjust our capital program in response to lower commodity prices. To mitigate some of the risk inherent in prices, we have utilized various derivative financial instruments to set minimum and maximum prices on a significant portion of our 2015 production. These hedges are expected to generate an estimated $2 billion of cash flow in 2015. Currently, our 2016 production is largely unhedged. If commodity prices remain consistent with 2015 and we are unable to obtain favorable hedge contracts for our 2016 production, we would expect our 2016 operating cash flow to be negatively impacted by approximately $2 billion. However, assuming current pricing expectations, we expect to generate low single-digit oil production growth in 2016, with an estimated exploration and production capital budget of $2.0 billion – $2.5 billion.
The key terms to our open oil, gas and NGL derivative financial instruments as of September 30, 2015 are presented in Note 3 in “Part I. Financial Information – Item 1. Financial Statements” in this report. Additionally, we anticipate utilizing our credit availability to provide additional liquidity as needed.
Credit Availability
As of September 30, 2015, we had $3.0 billion of available capacity under the Senior Credit Facility, net of letters of credit outstanding. This credit facility supports our $3.0 billion commercial paper program. At September 30, 2015, we had no outstanding commercial paper borrowings.
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The Senior Credit Facility contains only one material financial covenant. This covenant requires us to maintain a ratio of total funded debt to total capitalization, as defined in the credit agreement, to be no greater than 65%. As of September 30, 2015, we were in compliance with this covenant with a debt-to-capitalization ratio of 21.9%.
EnLink Capital Resources and Expenditures
EnLink has a $1.5 billion unsecured revolving credit facility, and the General Partner has a $250 million secured revolving credit facility. As of September 30, 2015, there were $2.8 million in outstanding letters of credit and $175 million outstanding borrowings under the $1.5 billion credit facility, and there were no outstanding borrowings under the $250 million credit facility.
On October 1, 2015, EnLink acquired Delaware Basin natural gas gathering and processing assets from Matador for approximately $143 million, subject to certain adjustments.
Critical Accounting Estimates
Full Cost Method of Accounting and Proved Reserves
We perform a full cost ceiling impairment test each quarter for our U.S. and Canadian oil and gas properties. The ceiling tests for the first three quarters of 2015 resulted in our recognizing ceiling impairments on our U.S. and Canadian properties totaling $14.3 billion and $336 million, respectively.
Depending on the relationship between our capitalized costs and calculated full cost ceiling at the time of the most recent ceiling test performed, uncertain future prices limit our ability to predict and measure potential future full cost impairments. However, because the ceiling test computation uses a 12-month trailing price to determine future cash flows, we can typically predict when circumstances will result in future impairments that are material, particularly in the next one to two quarters. However, due to the nature of estimating future cash flows, measuring any potential impairments is more difficult.
Based on prices from the first nine months of 2015 and the short-term pricing outlook for the remainder of 2015, we expect to recognize additional U.S. and Canadian full cost impairments in the fourth quarter of 2015. The U.S. impairment will be material to our net earnings, but we estimate it will not be as large as the $4.7 billion impairment we recognized in the third quarter of 2015. We expect to recognize an impairment related to our Canadian oil and gas properties in excess of the $336 million recognized in the third quarter of 2015. While difficult to measure, we estimate that the fourth quarter 2015 impairments will approximate $5 billion in the aggregate. Our full cost impairments will have no impact to our cash flow or liquidity.
We test goodwill for impairment annually at October 31, or more frequently if events or changes in circumstances dictate that the carrying value of goodwill may not be recoverable. Sustained weakness in the overall energy sector beginning in the fourth quarter of 2014 and continuing into 2015 driven by low commodity prices, together with a decline in the EnLink unit price, caused a change in circumstances warranting an interim impairment test for EnLink’s reporting units.
The goodwill assessment is performed at the reporting unit level and primarily utilizes a discounted cash flow analysis, supplemented by a market approach analysis in the assessment. Key assumptions in the analysis include the use of an appropriate discount rate, terminal year multiples and estimated future cash flows including volume forecasts and estimated operating and general and administrative costs. In estimating cash flows, current and historical market information, among other factors, are incorporated.
Using the fair value approaches described above, it was determined that the estimated fair value of EnLink’s Louisiana reporting unit was less than its carrying amount, primarily due to changes in assumptions related to commodity prices and discount rates. Through the analysis, a goodwill impairment of $576 million for EnLink’s Louisiana reporting unit was recognized in the third quarter of 2015. Subsequent to the impairment, we had $211 million of goodwill allocated to this reporting unit, the carrying value of which approximated the fair value.
No other goodwill impairment was identified or recorded for the remaining reporting units as a result of the interim goodwill assessment, as their estimated fair values were in excess of carrying values. However, the fair value of EnLink’s Crude and Condensate segment did not substantially exceed its carrying value. As of September 30, 2015, the fair value of EnLink’s Crude and
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Condensate reporting unit exceeded its carrying value by approximately 15%, and we had $142 million of goodwill allocated to this reporting unit.
Our impairment determinations involved significant assumptions and judgments, as discussed above. Differing assumptions regarding any of these inputs could have a significant effect on the various valuations. If actual future results are not consistent with these assumptions and estimates, or the assumptions and estimates change due to new information, we may be exposed to additional goodwill impairment charges, which would be recognized in the period in which we would determine that the carrying value exceeds fair value. We would expect that a prolonged or sustained period of lower commodity prices would adversely affect the estimate of future operating results, which could result in future goodwill impairments for other reporting units due to the potential impact on the cash flows of our operations.
The goodwill impairment has no effect on liquidity or capital resources. However, it adversely affects our results of operations in the period recognized.
In the third quarter of 2015, the assessment of customer relationships was updated due to the factors described in the aforementioned goodwill section. This assessment resulted in a $223 million impairment of other intangible assets related to EnLink’s Crude and Condensate reporting unit. Level 3 fair value measurements were utilized for the impairment analysis of definite-lived intangible assets, which included discounted cash flow estimates, consistent with those utilized in the goodwill impairment assessment.
The other intangible assets impairment has no effect on liquidity or capital resources. However, it adversely affects our results of operations in the period recognized.
Non-GAAP Measures
We make reference to “core earnings attributable to Devon” and “core earnings per share attributable to Devon” in “Overview of 2015 Results” in this Item 2 that are not required by or presented in accordance with GAAP. These non-GAAP measures should not be considered as alternatives to GAAP measures. Core earnings attributable to Devon, as well as the per share amount, represent net earnings excluding certain noncash or non-recurring items that are typically excluded by securities analysts in their published estimates of our financial results. Our non-GAAP measures are typically used as a quarterly performance measure. Amounts excluded for the first nine months of 2015 relate to derivatives and financial instrument fair value changes and noncash asset impairments. Amounts excluded for the first nine months of 2014 relate to derivatives and financial instrument fair value changes, our asset divestiture program, related gains on asset sales and related repatriation, deferred income tax on the formation of the General Partner and restructuring costs. We believe these non-GAAP measures facilitate comparisons of our performance to earnings estimates published by securities analysts. We also believe these non-GAAP measures can facilitate comparisons of our performance between periods and to the performance of our peers.
Below are reconciliations of our core earnings and earnings per share attributable to Devon to their comparable GAAP measures.
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Net earnings (loss) attributable to Devon (GAAP)
Adjustments (net of taxes and noncontrolling interests):
Noncash effect of derivatives and financial instruments
Current tax on property divestiture
Deferred tax on property divestiture
Gain on asset sales and related repatriation
Investment in General Partner deferred income tax
Core earnings attributable to Devon (non-GAAP)
Earnings (loss) per share attributable to Devon (GAAP)
Core earnings per share attributable to Devon (non-GAAP)
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Item 3. Quantitative and Qualitative Disclosures About Market Risk
Commodity Price Risk
We have commodity derivatives that pertain to a portion of our production for the last three months of 2015, as well as 2016 and 2017. The key terms to our open oil, gas and NGL derivative financial instruments as of September 30, 2015 are presented in Note 3 in “Part I. Financial Information – Item 1. Financial Statements” in this report.
The fair values of our commodity derivatives are largely determined by estimates of the forward curves of the relevant price indices. At September 30, 2015, a 10% change in the forward curves associated with our commodity derivative instruments would have changed our net asset positions by the following amounts:
Processing and fractionation derivatives
Interest Rate Risk
At September 30, 2015, we had total debt outstanding of $11.9 billion. Of this amount, $10.9 billion bears fixed interest rates averaging 5.3%. The remaining $1 billion of debt is comprised of floating rate debt that at September 30, 2015 had rates averaging 0.93%.
As of September 30, 2015, we had open interest rate swap positions that are presented in Note 3 in “Part I. Financial Information – Item 1. Financial Statements” in this report. The fair values of our interest rate swaps are largely determined by estimates of the forward curves of the 3-month LIBOR rate. A 10% change in these forward curves would not have materially impacted our balance sheet at September 30, 2015.
Foreign Currency Risk
Our net assets, net earnings and cash flows from our Canadian subsidiaries are based on the U.S. dollar equivalent of such amounts measured in the Canadian dollar functional currency. Assets and liabilities of the Canadian subsidiaries are translated to U.S. dollars using the applicable exchange rate as of the end of a reporting period. Revenues, expenses and cash flow are translated using an average exchange rate during the reporting period. A 10% unfavorable change in the Canadian-to-U.S. dollar exchange rate would not have materially impacted our balance sheet at September 30, 2015.
Our non-Canadian foreign subsidiaries have a U.S. dollar functional currency. However, one of these foreign subsidiaries holds Canadian-dollar cash and engages in short-term intercompany loans with Canadian subsidiaries that are based in Canadian dollars. The value of the Canadian-dollar cash and intercompany loans increases or decreases from the remeasurement of the cash and loans into the U.S. dollar functional currency. Additionally, at September 30, 2015, we held foreign currency exchange forward contracts to hedge exposures to fluctuations in exchange rates on the Canadian-dollar cash and intercompany loans. The increase or decrease in the value of the forward contracts is offset by the increase or decrease to the U.S. dollar equivalent of the Canadian-dollar cash and intercompany loans. Based on the amount of the cash and intercompany loans as of September 30, 2015, a 10% change in the foreign currency exchange rates would not have materially impacted our balance sheet.
Item 4. Controls and Procedures
Disclosure Controls and Procedures
We have established disclosure controls and procedures to ensure that material information relating to Devon, including its consolidated subsidiaries, is made known to the officers who certify Devon’s financial reports and to other members of senior management and the Board of Directors.
Based on their evaluation, our principal executive and principal financial officers have concluded that our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective as of September 30, 2015 to ensure that the information required to be disclosed by Devon in the reports that it files or submits under the
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Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC rules and forms.
Changes in Internal Control Over Financial Reporting
There were no changes in our internal control over financial reporting that occurred during our most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
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PART II. Other Information
Item 1. Legal Proceedings
There have been no material changes to the information included in Item 3. “Legal Proceedings” in our 2014 Annual Report on Form 10-K.
Item 1A. Risk Factors
There have been no material changes to the information included in Item 1A. “Risk Factors” in our 2014 Annual Report on Form 10-K.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
The following table provides information regarding purchases of our common stock that were made by us during the third quarter of 2015.
July 1 – July 31
August 1 – August 31
September 1 – September 30
Under the Devon Energy Corporation Incentive Savings Plan (the “Plan”), eligible employees may purchase shares of our common stock through an investment in the Devon Stock Fund (the “Stock Fund”), which is administered by an independent trustee. Eligible employees purchased approximately 18,700 shares of our common stock in the third quarter of 2015, at then-prevailing stock prices, that they held through their ownership in the Stock Fund. We acquired the shares of our common stock sold under the Plan through open-market purchases.
Similarly, under the Devon Canada Corporation Savings Plan (the “Canadian Plan”), eligible Canadian employees may purchase shares of our common stock through an investment in the Canadian Plan, which is administered by an independent trustee, Sun Life Assurance Company of Canada. Shares sold under the Canadian Plan were acquired through open-market purchases. These shares and any interest in the Canadian Plan were offered and sold in reliance on the exemptions for offers and sales of securities made outside of the U.S., including under Regulation S for offers and sales of securities to employees pursuant to an employee benefit plan established and administered in accordance with the law of a country other than the U.S. In the third quarter of 2015, there were no shares purchased by Canadian employees.
Item 3. Defaults Upon Senior Securities
Not applicable.
Item 4. Mine Safety Disclosures
Item 5. Other Information
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Item 6. Exhibits
(a) Exhibits required by Item 601 of Regulation S-K are as follows:
Exhibit
Number
Description
45
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
/s/ Jeremy D. Humphers
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INDEX TO EXHIBITS
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