Noble Energy (NBL) 10-Q 3 Aug 20 2020 Q2 Quarterly report Financial data

Cover Page

Cover Page	6 Months Ended
	Jun. 30, 2020shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2020
Document Transition Report	false
Entity File Number	001-07964
Entity Registrant Name	NOBLE ENERGY, INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	73-0785597
Entity Address, Address Line One	1001 Noble Energy Way
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77070
City Area Code	281
Local Phone Number	872-3100
Title of each class	Common Stock, $0.01 par value
Trading Symbol(s)	NBL
Name of each exchange on which registered	NASDAQ
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	479,768,764
Entity Central Index Key	0000072207
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q2
Amendment Flag	false

Consolidated Statements of Oper

Consolidated Statements of Operations and Comprehensive Loss - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Revenues
Revenue from sales	$ 571	$ 1,093	$ 1,591	$ 2,145
Total	571	1,093	1,591	2,145
Costs and Expenses
Production Expense	214	260	490	565
Exploration Expense	15	33	1,519	57
Depreciation, Depletion and Amortization	320	528	812	1,036
General and Administrative	63	105	148	207
Asset Impairments	51	0	2,754	0
Goodwill Impairment	0	0	110	0
Other Operating Expense, Net	73	22	117	139
Total	799	1,061	6,152	2,204
Operating (Loss) Income	(228)	32	(4,561)	(59)
Other Expense (Income)
Loss (Gain) on Commodity Derivative Instruments	158	(60)	(231)	152
Interest, Net of Amount Capitalized	87	63	168	129
Other Non-Operating Expense (Income), Net	3	1	(4)	5
Total	248	4	(67)	286
(Loss) Income Before Income Taxes	(476)	28	(4,494)	(345)
Income Tax (Benefit) Expense	(89)	20	(100)	(64)
Net (Loss) Income and Comprehensive (Loss) Income Including Noncontrolling Interests	(387)	8	(4,394)	(281)
Less: Net Income (Loss) and Comprehensive Income (Loss) Attributable to Noncontrolling Interests	21	18	(23)	42
Net Loss and Comprehensive Loss Attributable to Noble Energy	$ (408)	$ (10)	$ (4,371)	$ (323)
Net Loss Attributable to Noble Energy Common Shareholders per Share
Basic and Diluted ($ per share)	$ (0.85)	$ (0.02)	$ (9.11)	$ (0.68)
Weighted Average Number of Common Shares Outstanding
Basic and Diluted (in shares)	479	478	480	478
Oil, NGL and Gas Sales
Revenues
Revenue from sales	$ 493	$ 954	$ 1,387	$ 1,891
Sales of Purchased Oil and Gas
Revenues
Revenue from sales	49	103	174	177
Costs and Expenses
Cost of Purchased Oil and Gas	63	113	202	200
Other Revenue
Revenues
Revenue from sales	$ 29	$ 36	$ 30	$ 77

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Current Assets
Cash and Cash Equivalents	$ 324	$ 484
Accounts Receivable, Net	465	730
Other Current Assets	214	148
Total Current Assets	1,003	1,362
Property, Plant and Equipment
Oil and Gas Properties (Successful Efforts Method of Accounting)	30,941	30,404
Property, Plant and Equipment, Other	1,089	1,083
Total Property, Plant and Equipment, Gross	32,030	31,487
Accumulated Depreciation, Depletion and Amortization	(19,044)	(14,036)
Total Property, Plant and Equipment, Net	12,986	17,451
Other Noncurrent Assets	1,910	1,834
Total Assets	15,899	20,647
Current Liabilities
Accounts Payable – Trade	676	1,250
Other Current Liabilities	706	719
Total Current Liabilities	1,382	1,969
Long-Term Debt	7,936	7,477
Deferred Income Taxes	518	662
Other Noncurrent Liabilities	1,288	1,378
Total Liabilities	11,124	11,486
Commitments and Contingencies
Mezzanine Equity
Redeemable Noncontrolling Interest, Net	113	106
Shareholders’ Equity
Preferred Stock – Par Value $1.00 per share; 4 Million Shares Authorized; None Issued	0	0
Common Stock – Par Value $0.01 per share; 1 Billion Shares Authorized; 524 Million and 522 Million Shares Issued, respectively	5	5
Additional Paid in Capital	8,966	8,927
Accumulated Other Comprehensive Loss	(29)	(31)
Treasury Stock, at Cost; 39 Million Shares	(741)	(732)
(Accumulated Deficit) Retained Earnings	(4,198)	241
Noble Energy Share of Equity	4,003	8,410
Noncontrolling Interests	659	645
Total Shareholders' Equity	4,662	9,055
Total Liabilities, Mezzanine Equity and Shareholders' Equity	$ 15,899	$ 20,647

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Jun. 30, 2020	Dec. 31, 2019
Statement of Financial Position [Abstract]
Preferred stock, par value per share (in dollars per share)	$ 1	$ 1
Preferred stock, shares authorized (in shares)	4,000,000	4,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, par value per share (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	1,000,000,000	1,000,000,000
Common stock, shares issued (in shares)	524,000,000	522,000,000
Treasury stock, shares (in shares)	39,000,000	39,000,000

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Cash Flows From Operating Activities
Net Loss Including Noncontrolling Interests	$ (4,394)	$ (281)
Adjustments to Reconcile Net Loss to Net Cash Provided by Operating Activities
Leasehold Impairment	1,488	0
Depreciation, Depletion and Amortization	812	1,036
Deferred Income Tax Benefit	(144)	(101)
(Gain) Loss on Commodity Derivative Instruments	(231)	152
Net Cash Received in Settlement of Commodity Derivative Instruments	314	15
Asset Impairments	2,754	0
Goodwill Impairment	110	0
Finance Lease Impairment	40	0
Firm Transportation Exit Cost	0	92
Other Adjustments for Noncash Items Included in Income	108	59
Changes in Operating Assets and Liabilities
Decrease in Accounts Receivable	158	35
(Decrease) Increase in Accounts Payable	(296)	126
Increase in Partner Advances	0	132
Other Current Assets and Liabilities, Net	(225)	(108)
Other Operating Assets and Liabilities, Net	(94)	(65)
Net Cash Provided by Operating Activities	400	1,092
Cash Flows From Investing Activities
Additions to Property, Plant and Equipment	(724)	(1,405)
Additions to Equity Method Investments	(228)	(415)
Proceeds from Divestitures, Net	18	123
Other	(31)	0
Net Cash Used in Investing Activities	(965)	(1,697)
Cash Flows From Financing Activities
Proceeds from Revolving Credit Facility	1,300	50
Repayment of Revolving Credit Facility	(975)	(50)
Proceeds from Noble Midstream Services Revolving Credit Facility	350	560
Repayment of Noble Midstream Services Revolving Credit Facility	(210)	(250)
Proceeds from Commercial Paper Borrowings, Net	0	240
Dividends Paid, Common Stock	(68)	(111)
Contributions from Noncontrolling Interest Owners	81	21
Proceeds from Issuance of Mezzanine Equity, Net of Offering Costs	0	99
Other	(73)	(71)
Net Cash Provided by Financing Activities	405	488
Decrease in Cash, Cash Equivalents, and Restricted Cash	(160)	(117)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	484	719
Cash, Cash Equivalents, and Restricted Cash at End of Period	$ 324	$ 602

Consolidated Statements of Shar

Consolidated Statements of Shareholders' Equity - USD ($) $ in Millions	Total	Common Stock	Additional Paid in Capital	Accumulated Other Comprehensive Loss	Treasury Stock at Cost	(Accumulated Deficit) Retained Earnings	Non-controlling Interests
Balance at beginning of period at Dec. 31, 2018	$ 10,484	$ 5	$ 8,203	$ (32)	$ (730)	$ 1,980	$ 1,058
Increase (Decrease) in Stockholders' Equity
Net (Loss) Income	(289)					(313)	24
Stock-based Compensation	14		14
Dividends	(53)					(53)
Distributions to Noncontrolling Interest Owners	(17)						(17)
Contributions from Noncontrolling Interest Owners	10						10
Other	(6)		2		(5)		(3)
Balance at end of period at Mar. 31, 2019	10,143	5	8,219	(32)	(735)	1,614	1,072
Balance at beginning of period at Dec. 31, 2018	10,484	5	8,203	(32)	(730)	1,980	1,058
Increase (Decrease) in Stockholders' Equity
Net (Loss) Income	(281)
Balance at end of period at Jun. 30, 2019	10,104	5	8,244	(31)	(735)	1,546	1,075
Balance at beginning of period at Mar. 31, 2019	10,143	5	8,219	(32)	(735)	1,614	1,072
Increase (Decrease) in Stockholders' Equity
Net (Loss) Income	8					(10)	18
Stock-based Compensation	21		21
Dividends	(58)					(58)
Distributions to Noncontrolling Interest Owners	(19)						(19)
Contributions from Noncontrolling Interest Owners	11						11
Other	(2)		4	1			(7)
Balance at end of period at Jun. 30, 2019	10,104	5	8,244	(31)	(735)	1,546	1,075
Balance at beginning of period at Dec. 31, 2019	9,055	5	8,927	(31)	(732)	241	645
Increase (Decrease) in Stockholders' Equity
Net (Loss) Income	(4,007)					(3,963)	(44)
Stock-based Compensation	17		17
Dividends	(58)					(58)
Distributions to Noncontrolling Interest Owners	(29)						(29)
Contributions from Noncontrolling Interest Owners	78						78
Other	(10)		(2)	1	(8)		(1)
Balance at end of period at Mar. 31, 2020	5,046	5	8,942	(30)	(740)	(3,780)	649
Balance at beginning of period at Dec. 31, 2019	9,055	5	8,927	(31)	(732)	241	645
Increase (Decrease) in Stockholders' Equity
Net (Loss) Income	(4,394)
Balance at end of period at Jun. 30, 2020	4,662	5	8,966	(29)	(741)	(4,198)	659
Balance at beginning of period at Mar. 31, 2020	5,046	5	8,942	(30)	(740)	(3,780)	649
Increase (Decrease) in Stockholders' Equity
Net (Loss) Income	(387)					(408)	21
Stock-based Compensation	26		26
Dividends	(10)					(10)
Distributions to Noncontrolling Interest Owners	(14)						(14)
Contributions from Noncontrolling Interest Owners	3						3
Other	(2)		(2)	1	(1)
Balance at end of period at Jun. 30, 2020	$ 4,662	$ 5	$ 8,966	$ (29)	$ (741)	$ (4,198)	$ 659

Consolidated Statements of Sh_2

Consolidated Statements of Shareholders' Equity (Parenthetical) - $ / shares	3 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Mar. 31, 2019
Statement of Stockholders' Equity [Abstract]
Cash dividends per share (in dollars per share)	$ 0.02	$ 0.12	$ 0.12	$ 0.11

Organization and Nature of Oper

Organization and Nature of Operations	6 Months Ended
	Jun. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Nature of Operations	Note 1. Organization and Nature of Operations Noble Energy, Inc. (Noble Energy, we or us) is a leading independent energy company engaged in worldwide crude oil and natural gas exploration and production. Our historical operating areas include: US onshore, primarily the Denver-Julesburg (DJ) Basin, Delaware Basin and Eagle Ford Shale; Eastern Mediterranean; and West Africa. Our Midstream segment develops, owns and operates domestic midstream infrastructure assets, as well as invests in other midstream projects, with current focus areas being the DJ and Delaware Basins. Chevron Merger On July 20, 2020, we entered into a definitive merger agreement (the Chevron Merger Agreement) with Chevron Corporation (NYSE: CVX) pursuant to which, and subject to the conditions of the agreement, all outstanding shares of Noble Energy will be acquired by Chevron in an all-stock transaction valued at $13 billion, including debt, or $10.38 per share. Under the terms of the agreement, Noble Energy shareholders will receive 0.1191 shares of Chevron common stock for each Noble Energy share. The transaction was approved by the Boards of Directors of both companies and is anticipated to close in fourth quarter 2020. The transaction is subject to Noble Energy stockholder approval, regulatory approvals, and other customary closing conditions . See Item 1A. Risk Factors for a discussion of risks related to the Chevron Merger.

Basis of Presentation

Basis of Presentation	6 Months Ended
	Jun. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	Note 2. Basis of Presentation Presentation The accompanying unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the US (US GAAP) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and notes required by US GAAP for complete financial statements. The accompanying consolidated financial statements at June 30, 2020 and December 31, 2019 and for the three and six months ended June 30, 2020 and 2019 contain all normally recurring adjustments considered necessary for a fair presentation of our financial position, results of operations, cash flows and equity for such periods. Certain prior-period amounts have been reclassified to conform to the current period presentation. For the periods presented, net income or loss is materially consistent with comprehensive income or loss. Operating results for the three and six months ended June 30, 2020 are not necessarily indicative of the results that may be expected for the year ending December 31, 2020 . These consolidated financial statements should be read in conjunction with the consolidated financial statements and accompanying notes included in our Annual Report on Form 10-K for the year ended December 31, 2019 . Consolidation Our consolidated financial statements include our accounts, the accounts of subsidiaries which Noble Energy wholly owns, and the accounts of Noble Midstream Partners LP (Noble Midstream Partners). Noble Energy has determined that the partners with equity at risk in Noble Midstream Partners lack the authority, through voting rights or similar rights, to direct the activities that most significantly impact Noble Midstream Partners' economic performance; therefore, Noble Midstream Partners is considered a variable interest entity. Through Noble Energy's ownership interest in Noble Midstream GP LLC (the General Partner to Noble Midstream Partners), Noble Energy has the authority to direct the activities that most significantly affect economic performance and the obligation to absorb losses or the right to receive benefits that could be potentially significant to Noble Midstream Partners. Therefore, Noble Energy is considered the primary beneficiary and consolidates Noble Midstream Partners. In addition, we use the equity method of accounting for investments in entities that we do not control, but over which we exert significant influence. Amounts recorded within equity method investments, including contributions, include capitalized interest when the primary asset is under construction. All significant intercompany balances and transactions have been eliminated upon consolidation. Noncontrolling Interests Our consolidated financial statements include both noncontrolling interests and a redeemable noncontrolling interest. The noncontrolling interests represent the public's ownership in Noble Midstream Partners and third-party ownership in Noble Midstream Partners' consolidated non-wholly owned subsidiaries. Net loss attributable to noncontrolling interests for the six months ended June 30, 2020 includes goodwill impairment expense of $72 million based upon third party ownership interests in the underlying asset. See Note 4. Impairments . The redeemable noncontrolling interest represents perpetual preferred equity with a 6.5% annual dividend rate. Noble Midstream Partners may redeem the preferred equity in whole or in part at any time for cash at a predetermined redemption price. The preferred equity partner can request redemption at a pre-determined base return on or after March 25, 2025. Estimates The preparation of consolidated financial statements in conformity with US GAAP requires us to make a number of estimates and assumptions relating to the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Management evaluates estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic and commodity price environment. The current commodity price, supply and demand environment coupled with the COVID-19 pandemic have increased uncertainty related to our estimates for the six months ended June 30, 2020. Actual results could differ significantly from those estimates. Impairments We performed a review for impairment indicators related to our proved and unproved properties on a field-by-field basis as of June 30, 2020, concluding there were no indicators of impairment. Assumptions utilized within this review were consistent with those utilized in first quarter 2020, as outlined further below. Additionally, we performed impairment assessments over other long-lived assets, including property, plant and equipment, equity method investments, right-of-use assets and intangible assets. No impairment indicators were identified with the exception of certain capitalized exploratory well costs, as discussed below. We reviewed capitalized exploratory well costs to determine whether facts and circumstances support continued capitalization of such costs. These considerations included management's long-range plans, whether sufficient progress has been made in assessing reserves, and whether each project remains economically and operationally viable. During second quarter 2020, we recognized asset impairment expense related to the Felicita project, Block O, offshore Equatorial Guinea. See Note 4. Impairments and Note 6. Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs . During first quarter 2020, we identified certain impairment indicators including the significant decrease in commodity prices resulting from the COVID-19 pandemic, which lowered demand for our products, as well as the supply response from the Organization of Petroleum Exporting Countries (OPEC) and non-OPEC producers. Collectively, these factors caused us to change our development plans in first quarter 2020. Due to these impairment indicators, we conducted impairment testing of certain of our assets as of March 31, 2020, as follows: Proved Properties • Asset Recovery Test We conducted asset recovery testing of our proved properties on a field-by-field basis, inclusive of associated Midstream assets. For each field, we developed estimates of future undiscounted cash flows expected in connection with the property and compared these estimates to the carrying amount of the property. Assumptions used in these estimates included expectations for future commodity prices, development and capital spending plans, reservoir performance and production . Additionally, these estimates included certain asset specific assumptions, such as the political and regulatory impacts on future development activity, exploration plans, our geologists' evaluation of the property and the remaining lease term of the property. An impairment was indicated if, as a result of the assessment, an asset's carrying value exceeds its future net undiscounted cash flows. In preparing and reviewing assumptions used in the recovery test, we reassessed our historical methodology and rationale of inputs given the current industry and global environment. We concluded that our historical methodology and inputs were reasonable with the exception of estimating future commodity prices. Historically, management has relied on future undiscounted net cash flows which included five-year strip prices for crude oil and natural gas, with prices subsequent to the fifth year held constant, unless contractual arrangements designated the price to be used. This pricing methodology has been similar to pricing assumptions used in creating management's long-range plans for asset development and capital allocation decisions. However, during first quarter 2020, forward five-year strip prices experienced considerable volatility and limited liquidity in the outer years of the forward strip. As such, we concluded that estimating future commodity prices using only five-year strip pricing would not be representative of expected market prices for certain of the years within our undiscounted cash flow models. As such, absent contractual arrangements designating the price to be used, we aligned our future commodity price estimates used in the recovery test with those utilized in our updated long-range plans for asset development and capital allocation. This pricing reflects our analysis of market supply and demand considerations and industry cost of supply curve. Except for our Delaware Basin proved properties, we determined that the carrying amount of each field was recoverable. • Fair Value Determination We estimated the fair value of our Delaware Basin proved properties using a number of fair value inputs, which are Level 3 on the fair value hierarchy. We utilized a discounted cash flow model, estimating future net cash flows based on our expectations of future crude oil and natural gas production, commodity prices, and operating and development costs and discounted the cash flows using a weighted average cost of capital. As a result of the fair value determination, we concluded that the carrying amount of our Delaware Basin proved properties was impaired and recognized impairment expense for the excess of the carrying value above the fair value of the properties. See Note 4. Impairments . Unproved Properties Our unproved properties consist of leasehold costs and value allocated to probable and possible reserves resulting from acquisitions. During first quarter 2020, we assessed our unproved properties for impairment by considering numerous factors including, but not limited to, current development plans, favorable or unfavorable exploration activity on the property being evaluated and/or adjacent properties, our geologists' evaluation of the property, and the remaining months in the lease term for the property. We determined that the carrying values relating to both our Delaware Basin and Eagle Ford Shale unproved properties were impaired and recognized exploration expense. See Note 4. Impairments . Other Property, Plant & Equipment Other property includes lease right-of-use assets such as compressors and buildings, leasehold improvements, automobiles, trucks and other fixed assets. During first quarter 2020, we identified certain impairment indicators with regards to a corporate real estate finance lease. We performed an impairment assessment which indicated the right-of-use asset's carrying value exceeded its future net undiscounted cash flows. As such, in first quarter 2020 we estimated the fair value of the asset, recognizing impairment expense for the excess of the carrying value above the fair value of the right-of-use asset. See Note 4. Impairments . Equity Method Investments We consider our equity method investments to be essential components of our business and necessary and integral elements of our value chain in support of our upstream operations. We considered whether any facts or circumstances suggested that our equity method investments were impaired on an other-than-temporary basis and concluded that the carrying values of our equity method investments were not impaired. Goodwill Noble Midstream Partners recorded goodwill upon the acquisition of Saddle Butte Rockies Midstream, LLC and affiliates (collectively Saddle Butte and subsequently renamed Black Diamond). In first quarter 2020, the commodity price environment coupled with decreased market capitalization were indicators that goodwill may be impaired. Noble Midstream Partners performed a qualitative assessment, concluding it was more likely than not that the fair value of the reporting unit was less than its carrying value. As a result, Noble Midstream Partners performed a fair value assessment which took into account changes in customer development plans. Based on these assessments, Noble Midstream Partners concluded that the goodwill was fully impaired and recorded goodwill impairment expense in first quarter 2020. See Note 4. Impairments . Deferred Taxes We record valuation allowances to reduce deferred tax assets if it is more likely than not that some portion or all of the deferred tax assets will not be realized. In first quarter 2020, we changed our US onshore development plans in response to significant decreases in commodity prices, excess supply and lower demand for commodities resulting from the COVID-19 pandemic , as well as expected slower global economic growth. Additionally, in first quarter 2020 we recorded impairments to our Delaware Basin proved and unproved properties and to our Eagle Ford Shale unproved properties. Collectively, these factors suggested it was more likely than not that our forecasted domestic net deferred tax asset would not be realized and as such, we recorded a valuation allowance in first quarter 2020. See Note 10. Income Taxes . Revenue Recognition We recognize revenue at an amount that reflects the consideration we expect to be entitled to in exchange for transferring goods or services to a customer. We routinely monitor the credit worthiness of our purchasers. While we maintain credit insurance associated with certain purchasers, we do not carry credit insurance for all purchasers. In the Eastern Mediterranean, we sell natural gas under natural gas sales and purchase agreements (GSPAs) to customers in Israel, Egypt, and Jordan. The majority of these contracts include total contracted quantities for which we will deliver volumes to customers over the life of the agreements. As of June 30, 2020, a total of approximately 9.5 Tcf, gross ( 2.6 Tcf, net), of natural gas remained to be delivered under these contracts. Based on current production levels, our available quantities of proved reserves are more than sufficient to meet delivery commitments associated with these sales agreements with minimal additional capital investment. Certain of our Tamar and Leviathan GSPAs have buyer-minimum take or pay volume-obligations and index prices subject to minimum-price floor supports. In addition, our Egyptian export contracts include provisions which trigger adjustments to either decrease, or increase, fixed minimum take or pay volumes in the event the arithmetic average of daily Brent crude oil prices falls below, or rises above, $50 per barrel for certain periods of time. Our GSPAs do not preclude us from selling natural gas to customers, at amounts which exceed fixed minimum sales volumes. Estimated future net revenues related to remaining performance obligations subject to minimum sales volumes and base pricing as of June 30, 2020 were as follows: (millions) Remainder of 2020 2021 2022 2023 2024 Thereafter Total Natural Gas Revenues $ 298 $ 553 $ 546 $ 550 $ 552 $ 5,192 $ 7,691 Our actual future natural gas sales volumes may exceed future minimum volume commitments. Additionally, future natural gas revenues will vary due to variable consideration exceeding the contractual minimum volume or floor price provision. For example, estimates related to our Egyptian export contracts included in the table above calculate minimum fixed volume commitments assuming the arithmetic average of daily Brent crude oil prices are less than $50 per barrel for the remainder of the contract terms, which extend into 2035. In addition, these Egyptian export contracts include increases in minimum volume commitments up to 650 MMcf/d, gross, by mid-2022 once certain conditions precedent are satisfied. As of June 30, 2020, the table above reflects the increase in contractual minimum volumes to 450 MMcf/d, gross, from the Tamar and Leviathan fields. Actual results could differ significantly from these estimates. Recently Issued Accounting Standards London Interbank Offered Rate (LIBOR) Reform In first quarter 2020, the FASB issued ASU No. 2020-04 (ASU 2020-04): Reference Rate Reform (Topic 848), which provides optional guidance for a limited period of time to ease the transition from LIBOR to an alternative reference rate. The ASU intends to address certain concerns relating to accounting for contract modifications and hedge accounting. These optional expedients and exceptions to applying GAAP, assuming certain criteria are met, are allowed through December 31, 2022. We are currently evaluating the provisions of ASU 2020-04 and have not yet determined whether we will elect the optional expedients. We do not expect the transition to an alternative rate to have a significant impact on our business, operations or liquidity. Recently Adopted Accounting Standards Clarifying Certain Accounting Standards Codification (ASC) Topics In first quarter 2020, the FASB issued ASU No. 2020-01: Investments - Equity Securities (Topic 321), Investments - Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815) , to clarify the interactions between these Topics. The update provides clarifications for entities investing in equity securities accounted for under the ASC 321 measurement alternative and companies that hold certain non-derivative forward contracts and purchased options to acquire equity securities. ASU 2020-01 is effective for fiscal years beginning after December 15, 2020, with early adoption permitted. We early adopted this ASU in first quarter 2020. This adoption did not have a material impact on our financial statements. Statements of Operations Information Other statements of operations information is as follows: Three Months Ended June 30, Six Months Ended June 30, (millions) 2020 2019 2020 2019 Other Revenue Income (Loss) from Equity Method Investments and Other $ 3 $ 16 $ (21 ) $ 33 Midstream Services Revenues – Third Party 26 20 51 44 Total $ 29 $ 36 $ 30 $ 77 Production Expense Lease Operating Expense $ 98 $ 122 $ 236 $ 273 Production and Ad Valorem Taxes 24 41 63 90 Gathering, Transportation and Processing Expense 89 96 184 198 Other Royalty Expense 3 1 7 4 Total $ 214 $ 260 $ 490 $ 565 Exploration Expense Leasehold Impairment (1) $ 3 $ — $ 1,488 $ — Seismic, Staffing Expense and Other 12 33 31 57 Total $ 15 $ 33 $ 1,519 $ 57 Other Operating Expense, Net Finance Lease Right-of-Use Asset Impairment (2) $ — $ — $ 40 $ — Marketing Expense 10 14 19 19 Firm Transportation Exit Cost — — — 92 Corporate Restructuring (3) 30 1 30 1 Other, Net 33 7 28 27 Total $ 73 $ 22 $ 117 $ 139 (1) See Note 4. Impairments and Note 6. Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs . (2) See Note 4. Impairments . (3) Relates to cash severance, termination benefits and acceleration of stock-based compensation for workforce reduction. Balance Sheet Information Other balance sheet information is as follows: (millions) June 30, December 31, Accounts Receivable, Net Commodity Sales $ 270 $ 446 Joint Interest Billings 115 164 Other 88 128 Current Expected Credit Losses (8 ) (8 ) Total $ 465 $ 730 Other Current Assets Commodity Derivative Assets $ 61 $ 14 Inventory - Materials and Supplies 68 59 Assets Held for Sale 2 14 Prepaid Expenses and Other Current Assets 83 61 Total $ 214 $ 148 Other Noncurrent Assets Equity Method Investments $ 1,246 $ 1,066 Operating Lease Right-of-Use Assets, Net (1) 225 227 Customer-Related Intangible Assets, Net (2) 262 278 Goodwill (3) — 110 Other Assets, Noncurrent 177 153 Total $ 1,910 $ 1,834 Other Current Liabilities Production and Ad Valorem Taxes $ 109 $ 118 Commodity Derivative Liabilities 151 36 Asset Retirement Obligations 89 84 Interest Payable 59 74 Operating Lease Liabilities 79 88 Compensation and Benefits Payable 53 126 Other Liabilities, Current 166 193 Total $ 706 $ 719 Other Noncurrent Liabilities Deferred Compensation Liabilities $ 121 $ 133 Asset Retirement Obligations 732 730 Operating Lease Liabilities 169 164 Firm Transportation Exit Cost Accrual (4) 113 129 Other Liabilities, Noncurrent 153 222 Total $ 1,288 $ 1,378 (1) Balance includes a five -year $28 million lease renewal executed in first quarter 2020 for a vessel offshore West Africa. (2) Balances at June 30, 2020 and December 31, 2019 are net of accumulated amortization of $78 million and $62 million , respectively. (3) See Note 4. Impairments . (4) Represents the discounted present value of our remaining obligations to third parties for permanent assignments of capacity on pipelines in the Marcellus Shale. Reconciliation of Total Cash We define total cash as cash, cash equivalents and restricted cash. Carrying amounts approximate fair value due to the short-term nature. The following table provides a reconciliation of total cash: Six Months Ended June 30, (millions) 2020 2019 Cash and Cash Equivalents at Beginning of Period $ 484 $ 716 Restricted Cash at Beginning of Period — 3 Cash, Cash Equivalents, and Restricted Cash at Beginning of Period $ 484 $ 719 Cash and Cash Equivalents at End of Period $ 324 $ 470 Restricted Cash at End of Period — 132 Cash, Cash Equivalents, and Restricted Cash at End of Period $ 324 $ 602

Segment Information

Segment Information	6 Months Ended
	Jun. 30, 2020
Segment Reporting [Abstract]
Segment Information	Note 3. Segment Information We have the following reportable segments: US onshore; Eastern Mediterranean (Israel, Egypt and Cyprus); West Africa (Equatorial Guinea, Cameroon and Gabon until June 2020); Other International (Canada, Colombia and New Ventures); and Midstream. The Midstream segment includes the consolidated accounts of Noble Midstream Partners. The geographical reportable segments (US onshore, Eastern Mediterranean, West Africa and Other International) are in the business of crude oil and natural gas acquisition and exploration, development, and production (Oil and Gas Exploration and Production). The Midstream reportable segment develops, owns and operates domestic midstream infrastructure assets, as well as invests in other midstream projects, with current focus areas being the DJ and Delaware Basins. Expenses related to debt, such as interest and other debt-related costs, headquarters depreciation, corporate general and administrative expenses, exit costs, corporate restructurings, and certain costs associated with mitigating the effects of our retained Marcellus Shale transportation agreements, are recorded in the Corporate reportable segment. The chief operating decision maker analyzes (loss) income before income taxes to assess the performance of Noble Energy's reportable segments as management believes this measure provides useful information in assessing our operating and financial performance across periods. Oil and Gas Exploration and Production Midstream (millions) Consolidated United States Eastern Mediter-ranean West Africa Other Int'l United States Intersegment Eliminations and Other (1) Corporate Three Months Ended June 30, 2020 Crude Oil Sales $ 261 $ 230 $ — $ 31 $ — $ — $ — $ — NGL Sales 40 40 — — — — — — Natural Gas Sales 192 48 139 5 — — — — Total Crude Oil, NGL and Natural Gas Sales 493 318 139 36 — — — — Sales of Purchased Oil and Gas 49 4 — — — 29 — 16 Income (Loss) from Equity Method Investments and Other 3 (1 ) (1 ) 8 — (3 ) — — Midstream Services Revenues – Third Party 26 — — — — 26 — — Intersegment Revenues — — — — — 92 (92 ) — Total Revenues 571 321 138 44 — 144 (92 ) 16 Lease Operating Expense 98 81 15 20 — (1 ) (17 ) — Production and Ad Valorem Taxes 24 23 — — — 1 — — Gathering, Transportation and Processing Expense 89 133 3 — — 20 (67 ) — Other Royalty Expense 3 3 — — — — — — Total Production Expense 214 240 18 20 — 20 (84 ) — Exploration Expense 15 5 2 5 3 — — — Oil and Gas Exploration and Production Midstream (millions) Consolidated United States Eastern Mediter-ranean West Africa Other Int'l United States Intersegment Eliminations and Other (1) Corporate Depreciation, Depletion and Amortization 320 252 16 22 — 26 (8 ) 12 Cost of Purchased Oil and Gas 63 4 — — — 29 — 30 Asset Impairments 51 — — 51 — — — — Loss on Commodity Derivative Instruments 158 149 — 9 — — — — (Loss) Income Before Income Taxes (476 ) (359 ) 83 (69 ) (6 ) 58 11 (194 ) Additions to Long-Lived Assets, Excluding Acquisitions 106 65 13 19 2 5 (4 ) 6 Additions to Equity Method Investments 3 — — — — 3 — — Three Months Ended June 30, 2019 Crude Oil Sales $ 688 $ 617 $ 2 $ 69 $ — $ — $ — $ — NGL Sales 84 84 — — — — — — Natural Gas Sales 182 72 105 5 — — — — Total Crude Oil, NGL and Natural Gas Sales 954 773 107 74 — — — — Sales of Purchased Oil and Gas 103 28 — — — 52 — 23 Income (Loss) from Equity Method Investments and Other 16 1 — 17 — (2 ) — — Midstream Services Revenues – Third Party 20 — — — — 20 — — Intersegment Revenues — — — — — 91 (91 ) — Total Revenues 1,093 802 107 91 — 161 (91 ) 23 Lease Operating Expense 122 114 9 10 — 1 (12 ) — Production and Ad Valorem Taxes 41 40 — — — 1 — — Gathering, Transportation and Processing Expense 96 124 — — — 31 (59 ) — Other Royalty Expense 1 1 — — — — — — Total Production Expense 260 279 9 10 — 33 (71 ) — Depreciation, Depletion and Amortization 528 457 17 19 — 26 (6 ) 15 Cost of Purchased Oil and Gas 113 28 — — — 48 — 37 Gain on Commodity Derivative Instruments (60 ) (58 ) — (2 ) — — — — Income (Loss) Before Income Taxes 28 70 65 59 (15 ) 46 (15 ) (182 ) Additions to Long-Lived Assets, Excluding Acquisitions 647 478 119 12 2 52 (25 ) 9 Additions to Equity Method Investments 144 — — — — 144 — — Six Months Ended June 30, 2020 Crude Oil Sales $ 839 $ 722 $ 1 $ 116 $ — $ — $ — $ — NGL Sales 102 102 — — — — — — Natural Gas Sales 446 108 329 9 — — — — Oil and Gas Exploration and Production Midstream (millions) Consolidated United States Eastern Mediter-ranean West Africa Other Int'l United States Intersegment Eliminations and Other (1) Corporate Total Crude Oil, NGL and Natural Gas Sales 1,387 932 330 125 — — — — Sales of Purchased Oil and Gas 174 29 — — — 112 — 33 Loss from Equity Method Investments and Other (21 ) (1 ) (3 ) (9 ) — (8 ) — — Midstream Services Revenues – Third Party 51 — — — — 51 — — Intersegment Revenues — — — — — 207 (207 ) — Total Revenues 1,591 960 327 116 — 362 (207 ) 33 Lease Operating Expense 236 189 28 50 — — (31 ) — Production and Ad Valorem Taxes 63 60 — — — 3 — — Gathering, Transportation and Processing Expense 184 279 6 — — 41 (142 ) — Other Royalty Expense 7 7 — — — — — — Total Production Expense 490 535 34 50 — 44 (173 ) — Exploration Expense 1,519 1,499 4 8 8 — — — Depreciation, Depletion and Amortization 812 671 35 46 — 52 (17 ) 25 Cost of Purchased Oil and Gas 202 32 — — — 109 — 61 Asset Impairments 2,754 2,703 — 51 — — — — Goodwill Impairment 110 — — — — 110 — — (Gain) Loss on Commodity Derivative Instruments (231 ) (240 ) — 9 — — — — (Loss) Income Before Income Taxes (4,494 ) (4,276 ) 228 (59 ) (12 ) 27 — (402 ) Additions to Long-Lived Assets, Excluding Acquisitions 548 422 44 38 11 48 (28 ) 13 Additions to Equity Method Investments 155 — — — — 155 — — Six Months Ended June 30, 2019 Crude Oil Sales $ 1,300 $ 1,162 $ 3 $ 135 $ — $ — $ — $ — NGL Sales 180 180 — — — — — — Natural Gas Sales 411 180 222 9 — — — — Total Crude Oil, NGL and Natural Gas Sales 1,891 1,522 225 144 — — — — Sales of Purchased Oil and Gas 177 42 — — — 85 — 50 Income from Equity Method Investments and Other 33 1 — 32 — — — — Midstream Services Revenues – Third Party 44 — — — — 44 — — Intersegment Revenues — — — — — 197 (197 ) — Total Revenues 2,145 1,565 225 176 — 326 (197 ) 50 Lease Operating Expense 273 239 19 34 — 2 (21 ) — Production and Ad Valorem Taxes 90 87 — — — 3 — — Gathering, Transportation and Processing Expense 198 266 — — — 60 (128 ) — Oil and Gas Exploration and Production Midstream (millions) Consolidated United States Eastern Mediter-ranean West Africa Other Int'l United States Intersegment Eliminations and Other (1) Corporate Other Royalty Expense 4 4 — — — — — — Total Production Expense 565 596 19 34 — 65 (149 ) — Depreciation, Depletion and Amortization 1,036 896 33 39 — 51 (13 ) 30 Cost of Purchased Oil and Gas 200 42 — — — 79 — 79 Firm Transportation Exit Cost 92 — — — — — — 92 Loss on Commodity Derivative Instruments 152 130 — 22 — — — — (Loss) Income Before Income Taxes (345 ) (177 ) 149 70 (31 ) 119 (29 ) (446 ) Additions to Long-Lived Assets, Excluding Acquisitions 1,359 990 251 18 12 118 (48 ) 18 Investments in Equity Method Investees 415 — — — — 415 — — June 30, 2020 Property, Plant and Equipment, Net $ 12,986 $ 7,473 $ 3,058 $ 737 $ 55 $ 1,721 $ (222 ) $ 164 December 31, 2019 Property, Plant and Equipment, Net $ 17,451 $ 11,859 $ 3,041 $ 793 $ 44 $ 1,721 $ (223 ) $ 216 (1)

Impairments Impairments

Impairments Impairments	6 Months Ended
	Jun. 30, 2020
Other Income and Expenses [Abstract]
Impairments	Note 4. Impairments The effect of impairments on our consolidated statements of operations and comprehensive loss was as follows: Three Months Ended June 30, Six Months Ended June 30, (millions) Statement of Operations Location 2020 2019 2020 2019 Asset Impairment Expense Proved Property Impairment - Delaware Basin Asset Impairments $ — $ — $ 2,703 $ — Capitalized Exploratory Well Costs - Felicita Asset Impairments 51 — 51 — Total Asset Impairment Expense $ 51 $ — $ 2,754 $ — Leasehold Impairment Expense Leasehold Impairment - Delaware Basin Exploration Expense $ — $ — $ 1,385 $ — Leasehold Impairment - Eagle Ford Shale Exploration Expense — — 100 — Leasehold Impairment - Gabon Exploration Expense 3 — 3 — Total Leasehold Impairment Expense $ 3 $ — $ 1,488 $ — Goodwill Impairment - Noble Midstream Partners Goodwill Impairment $ — $ — $ 110 $ — Finance Lease Right-of-Use Asset Impairment Other Operating Expense, Net — — 40 — Second Quarter 2020 Impairment In second quarter 2020, we concluded that while our 2008 Felicita discovery, Block O, offshore West Africa was successful in locating hydrocarbons, it was not competitive with other assets in our portfolio being considered for future development. We fully impaired the asset based on management's decision not to move forward with development. First Quarter 2020 Impairments We performed a number of impairment assessments during first quarter 2020. These assessments included using various valuation techniques and Level 3 inputs on the fair value hierarchy. See Note 2. Basis of Presentation . Property Impairments In first quarter 2020, following our impairment analysis, we recorded impairment expense as follows: • Delaware Basin Assets The fair values of our Delaware Basin assets were estimated using the income approach and resulted in fair values of approximately $910 million and $530 million associated with proved properties (inclusive of associated midstream assets) and unproved properties, respectively. As of March 31, 2020, the carrying values of our Delaware Basin proved and unproved properties were $3.6 billion and $1.9 billion , respectively, and as such, we recognized total impairment expense of $4.1 billion for the excess of the carrying value above the fair value of the properties. • Eagle Ford Shale Unproved Properties After assessing future development scenarios and in contemplation of the current commodity and supply/demand environment, we determined that all $ 100 million of remaining unproved leasehold costs were impaired due to the likelihood of future drilling in certain zones in this area. Goodwill Impairment Noble Midstream Partners concluded the fair value of its Black Diamond reporting unit was less than its carrying value and therefore performed a fair value assessment. Based on the assessment, Noble Midstream Partners concluded that the entire carrying amount of goodwill was fully impaired and recorded goodwill impairment expense of $110 million in first quarter 2020. Of the $110 million of goodwill impairment expense included in our consolidated statements of operations, approximately $38 million is attributable to Noble Energy relating to our ownership interests in the Black Diamond entity, while the remainder of $72 million is attributable to noncontrolling interests. Finance Lease Right-of-Use Asset Impairment During first quarter 2020, we recognized $40 million of impairment expense for the excess of the carrying value above the fair value of the right-of-use asset relating to a corporate real estate lease. As of March 31, 2020, the associated carrying value was $88 million

Acquisitions, Divestitures and

Acquisitions, Divestitures and Equity Method Investments	6 Months Ended
	Jun. 30, 2020
Discontinued Operations and Disposal Groups [Abstract]
Acquisitions, Divestitures and Equity Method Investments	Note 5. Acquisitions, Divestitures and Equity Method Investments We maintain an ongoing portfolio management program and have engaged in various transactions over recent years. 2020 Transactions Saddlehorn In February 2020, Black Diamond Gathering LLC (Black Diamond), in which Noble Midstream Partners owns a 54.4% interest, exercised its option to acquire a 20% ownership interest in Saddlehorn Pipeline Company, LLC (Saddlehorn) for $160 million ( $87 million, net to Noble Midstream Partners). Saddlehorn owns a pipeline that transports crude oil and condensate from the DJ and Powder River Basins to storage facilities in Cushing, Oklahoma. Noble Midstream Partners consolidates Black Diamond and the Saddlehorn investment is accounted for using the equity method. EPIC Pipelines In first quarter 2019, Noble Midstream Partners exercised and closed options with EPIC Midstream Holdings, LP (EPIC) to acquire a 15% equity interest in EPIC Y-Grade, LP (EPIC Y-Grade), which constructed the EPIC Y-Grade pipeline, and a 30% equity interest in EPIC Crude Holdings, which constructed the EPIC crude oil pipeline. The EPIC crude oil pipeline supports transportation of our production from the Delaware Basin to Corpus Christi, Texas. For the first six months of 2020, Noble Midstream Partners made capital contributions to EPIC Y-Grade and EPIC Crude Holdings of $ 14 million and $ 33 million, respectively. As of April 1, 2020 the EPIC crude oil pipeline commenced full service. EPIC Y-Grade began the transition to full NGL service in May and completed construction of its new build fractionator in June 2020. Additionally, in December 2019, Noble Midstream Partners exercised and closed an option with EPIC to acquire an interest in EPIC Propane, which is constructing a propane pipeline that will run from Robstown, Texas to Sweeney, Texas, with additional connectivity to the Markham underground storage caverns. For the first six months of 2020, Noble Midstream Partners made capital contributions to EPIC Propane of $4 million . Delaware Crossing Joint Venture In February 2019, Noble Midstream Partners executed definitive agreements with Salt Creek Midstream LLC (Salt Creek) to form a 50 / 50 joint venture, Delaware Crossing LLC (Delaware Crossing), in order to construct a 160 MBbl/d day crude oil pipeline system in the Delaware Basin, which began delivering crude oil into all connection points in April 2020. In the first six months of 2020, Noble Midstream Partners made capital contributions to Delaware Crossing of $ 17 million. 2019 Transactions Divestiture of Reeves County Assets In February 2019, we closed the sale of certain proved and unproved non-core acreage in the Delaware Basin totaling approximately 13,000 net acres in Reeves County, Texas. We received cash consideration of approximately $131 million , recognizing no gain or loss on the sale. EPIC Pipelines In first quarter 2019, Noble Midstream Partners exercised and closed options with EPIC totaling $ 227 million. In second quarter 2019, Noble Midstream Partners contributed $28 million and $114 million to EPIC Y-Grade and EPIC Crude Holdings, respectively. Delaware Crossing Joint Venture During the first six months of 2019, Noble Midstream Partners made capital contributions of $ 39

Capitalized Exploratory Well Co

Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs	6 Months Ended
	Jun. 30, 2020
Extractive Industries [Abstract]
Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs	Note 6. Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs Cap italized Exploratory Well Costs Changes in capitalized exploratory well costs are as follows and exclude amounts that were capitalized and subsequently expensed in the same period: (millions) Six Months Ended June 30, 2020 Capitalized Exploratory Well Costs, Beginning of Period $ 280 Additions to Capitalized Exploratory Well Costs Pending Determination of Proved Reserves 15 Capitalized Exploratory Well Costs Charged to Expense (1) (51 ) Capitalized Exploratory Well Costs, End of Period $ 244 (1) Relates to second quarter 2020 impairment of Felicita discovery, Block O, offshore Equatorial Guinea; see Note 2. Basis of Presentation and Note 4. Impairments . The following table provides an aging of capitalized exploratory well costs based on the date that drilling commenced: (millions, except number of projects) June 30, December 31, Exploratory Well Costs Capitalized for a Period of One Year or Less $ 30 $ 22 Exploratory Well Costs Capitalized for a Period Greater Than One Year Since Commencement of Drilling 214 258 Capitalized Exploratory Well Costs, End of Period $ 244 $ 280 Number of Projects with Exploratory Well Costs That Have Been Capitalized for a Period Greater Than One Year Since Commencement of Drilling 4 5 Undeveloped Leasehold Costs Changes in undeveloped leasehold costs are as follows: (millions) Six Months Ended June 30, 2020 Undeveloped Leasehold Costs, Beginning of Period $ 2,152 Additions to Undeveloped Leasehold Costs 2 Impairment (1) (1,488 ) Other (2 ) Undeveloped Leasehold Costs, End of Period $ 664 (1) Includes first quarter 2020 impairments of undeveloped leasehold costs for unproved properties in the Delaware Basin and Eagle Ford Shale of $ 1.5 billion collectively and $ 3 million related to our decision not to pursue lease renewal of undeveloped acreage in Gabon. See Note 2. Basis of Presentation and Note 4. Impairments . As of June 30, 2020 , undeveloped leasehold costs included $530 million, $80 million, and $54 million attributable to the Delaware Basin, other US onshore properties and international properties, respectively. Certain of these costs pertain to acquired leases or licenses that are subject to expiration over the next several years unless production is established on the acreage, while other costs pertain to acreage that is being held by production.

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2020
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Note 7. Asset Retirement Obligations Asset retirement obligations (ARO) consist primarily of estimated costs of dismantlement, removal, site reclamation and similar activities associated with our oil and gas properties. Changes in ARO are as follows: Six Months Ended June 30, (millions) 2020 2019 Asset Retirement Obligations, Beginning Balance $ 814 $ 880 Liabilities Incurred 19 15 Liabilities Settled (42 ) (56 ) Revisions of Estimates 9 (70 ) Accretion Expense 21 23 Asset Retirement Obligations, Ending Balance $ 821 $ 792 Six Months Ended June 30, 2020 Liabilities incurred primarily relate to properties in Israel and the DJ Basin. Liabilities settled primarily relate to abandonment of US onshore properties, with $ 35 million in the DJ Basin where we have engaged in a program to plug and abandon older vertical wells. Costs associated with these abandonment activities will be incurred over several years. The revision of estimates is due to changes in both timing of spend and cost in the DJ Basin. Six Months Ended June 30, 2019 Liabilities settled relate to abandonment of US onshore properties, primarily in the DJ Basin where we have engaged in a program to plug and abandon older vertical wells. Costs associated with these abandonment activities will be incurred over several years. Revisions of estimates primarily relate to a decrease of $73 million

Debt

Debt	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Debt	Note 8. Debt Debt consists of the following: June 30, 2020 December 31, 2019 (millions, except percentages) Debt Interest Rate Debt Interest Rate Noble Energy, Excluding Noble Midstream Partners Revolving Credit Facility, due March 9, 2023 $ 325 1.41 % $ — — % Senior Notes and Debentures 5,884 (1 ) 5,884 (1 ) Finance Lease Obligations 193 — % 205 — % Total Noble Energy Debt, Excluding Noble Midstream Partners Debt 6,402 6,089 Noble Midstream Partners Noble Midstream Services Revolving Credit Facility, due March 9, 2023 735 1.61 % 595 3.11 % Noble Midstream Services Term Loan Credit Facility, due July 31, 2021 500 1.36 % 500 2.85 % Noble Midstream Services Term Loan Credit Facility, due August 23, 2022 400 1.24 % 400 2.74 % Total Noble Midstream Partners Debt 1,635 1,495 Total Debt 8,037 7,584 Net Unamortized Discounts and Debt Issuance Costs (63 ) (65 ) Total Debt, Net of Unamortized Discounts and Debt Issuance Costs 7,974 7,519 Less Amounts Due Within One Year Finance Lease Obligations (38 ) (42 ) Long-Term Debt Due After One Year $ 7,936 $ 7,477 (1) The Senior Notes and Debentures have weighted average interest rates of 4.93% at June 30, 2020 and December 31, 2019 . Revolving Credit Facilities and Commercial Paper Program We have total borrowing capacity of $4.0 billion across our Revolving Credit Facility and our commercial paper program, which is backed by our Revolving Credit Facility. We choose to borrow under the commercial paper program or Revolving Credit Facility based on market availability and interest rates at the time of borrowing. During first quarter 2020, we borrowed $1.0 billion , net, on our Revolving Credit Facility to increase our cash on hand balance to mitigate potential future issues in the global financial system . During second quarter 2020, we reduced our outstanding borrowings by $675 million , net, leaving $325 million outstanding as of June 30, 2020. As of June 30, 2020 and December 31, 2019 , the Revolving Credit Facility had $ 3.7 billion and $ 4.0 billion available for borrowing, respectively. As of June 30, 2020 and December 31, 2019 , the Noble Midstream Services Revolving Credit Facility had $ 415 million and $ 555 million available for borrowing, respectively. Fair Value of Debt The fair value of fixed-rate, public debt is estimated based on observable and available market information. As such, we consider the fair value of this debt to be a Level 1 measurement on the fair value hierarchy. Our non-public debt outstanding, including our Revolving Credit Facility, Noble Midstream Services Revolving Credit Facility and Noble Midstream Services term loans are subject to variable interest rates. The fair value is estimated based on significant other observable inputs; thus, we consider the fair values to be Level 2 measurements on the fair value hierarchy. Fair value information regarding our debt, which excludes finance lease obligations, is as follows: June 30, 2020 December 31, 2019 (millions) Carrying Amount Fair Value Carrying Amount Fair Value Debt $ 7,844 $ 7,529 $ 7,379 $ 8,033

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 9. Commitments and Contingencies Legal Proceedings We are involved in various legal proceedings in the ordinary course of business. These proceedings are subject to the uncertainties inherent in any litigation. We are defending ourselves vigorously in all such matters, and we believe that the ultimate disposition of such proceedings will not have a material adverse effect on our financial position, results of operations or cash flows. Bureau of Safety and Environmental Enforcement Penalty Assessment In July 2020, we received a penalty assessment of approximately $136,000 from the federal Bureau of Safety and Environmental Enforcement related to an alleged unauthorized discharge from an offshore platform located in the Gulf of Mexico, formerly owned by Noble Energy and sold to Fieldwood Energy, Inc. (Fieldwood), in April 2018. The unauthorized discharge is alleged to have occurred in May 2018, during the transition period when Noble Energy operated the platform on behalf of Fieldwood. Fieldwood is required to fully indemnify Noble Energy for any liabilities that arose during the transition period. Noble Energy has notified Fieldwood of the penalty and is currently seeking a resolution of this matter with Fieldwood. While we cannot predict the outcome of this matter, we do not believe the resolution will have a material adverse effect on our financial position, results of operations or cash flows. MOEP Notifications In April and May 2020, we received two separate notices of intent (NOIs) from Israel’s Ministry of Environmental Protection (MOEP), notifying us of potential enforcement and imposition of monetary sanctions for alleged violations of Israeli environmental laws relating to our Leviathan facility. MOEP’s April NOI alleges breaches of the Leviathan facility’s effluent discharge permit for discharges that occurred primarily before startup of the Leviathan facility and seeks a penalty of approximately $1.2 million , net to the Company's interest in the Leviathan facility, pursuant to Israel’s Prevention of Sea Pollution from Land-Based Sources Law. In the May NOI, MOEP alleges violations of the Leviathan facility's air permit for the alleged failure to transmit to MOEP continuous monitoring data for flares, along with other alleged administrative infractions of Israel's Clean Air Law. Pursuant to Israel's Clean Air Law, MOEP seeks a penalty of approximately $147,000 , net to the Company's interest in the Leviathan facility. In July 2020, a NOI was received from the MOEP notifying us of a potential enforcement and imposition of a monetary sanction of approximately $632,000 , net to the Company's interest in the Leviathan facility, pursuant to the Clean Air Law following alleged violations of the emissions permit during the activation of the Leviathan facility's flares. We have discussed the NOIs with MOEP enforcement staff and anticipate further meetings regarding a potential settlement of the alleged violations. Given the ongoing status of settlement discussions, we are currently unable to predict the ultimate outcome of this action, but believe the resolution will not have a material adverse effect on our financial position, results of operations or cash flows. Colorado FracFocus Matter In July 2019, we received a Notice of Alleged Violation (NOAV) from the Colorado Oil and Gas Conservation Commission (COGCC) advising us of alleged violations of COGCC rules for delinquent disclosures to the FracFocus Chemical Disclosure Registry following commencement of certain hydraulic fracturing activities. We responded to the NOAV in July 2019, confirming with the COGCC that required disclosures had been made prior to issuance of the NOAV. In May 2020, COGCC enforcement staff proposed an administrative penalty in the amount of approximately $149,000 to resolve the enforcement of this matter. We are in the process of reviewing the proposed settlement document. Given the ongoing status of settlement discussions, we are currently unable to predict the ultimate outcome of this action, but believe the resolution will not have a material adverse effect on our financial position, results of operations or cash flows. Colorado Clean Water Act Referral Notice In September 2018, we received a letter from the Department of Justice (DOJ) providing notification of referral from the Environmental Protection Agency (EPA) of alleged Clean Water Act violations at an upstream production facility and a midstream gathering facility in Weld County, Colorado. In April 2019, we met with the DOJ and EPA enforcement personnel to discuss potential settlement of the alleged violations. Given the ongoing status of settlement discussions, we are currently unable to predict the ultimate outcome of this action, but believe the resolution will not have a material adverse effect on our financial position, results of operations or cash flows.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2020
Income Tax Disclosure [Abstract]
Income Taxes	Note 10. Income Taxes Income tax (benefit) expense consists of the following: Three Months Ended June 30, Six Months Ended June 30, (millions, except percentages) 2020 2019 2020 2019 Current $ 7 $ 21 $ 44 $ 37 Deferred (96 ) (1 ) (144 ) (101 ) Total Income Tax (Benefit) Expense $ (89 ) $ 20 $ (100 ) $ (64 ) Effective Tax Rate 18.7 % 71.4 % 2.2 % 18.6 % Effective Tax Rate (ETR) At the end of each interim period, we apply a forecasted annualized ETR to current period earnings or loss before tax, which can produce interim ETR fluctuations. We have concluded that the annual ETR is a reliable estimate considering recent economic and financial market effects of decreased commodity prices and COVID-19. In first quarter 2020, as a result of impairments recorded during the quarter, we further evaluated our ability to utilize domestic federal and state net operating loss (NOL) and credit carryforwards prior to expiration, concluding a valuation allowance should be recorded for the associated deferred tax assets. See Note 4. Impairments . The ETR for the six months ended June 30, 2020 decreased as compared with the same period 2019 , primarily due to the valuation allowance discussed above which significantly reduced the deferred tax benefit recorded for the current year loss. The deferred tax benefit was further reduced by the $470 million of deferred tax expense associated with the valuation allowance on losses generated in prior years recorded as a discrete item in first quarter 2020. Impact of the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) We evaluated provisions of the CARES Act, signed into law on March 27, 2020. Certain provisions of the CARES Act include modifications to NOL limitations and business interest expense limitations, which are expected to impact utilization of future NOL carryovers. The provisions did not have a material impact on our financial statements for the period ended June 30, 2020. Tax Examinations In our major tax jurisdictions, the earliest years remaining open to examination are as follows: US – 2014 , Israel – 2015 (2013 with respect to Israel Oil Profits Tax) and Equatorial Guinea – 2013 .

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	6 Months Ended
	Jun. 30, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Note 11. Derivative Instruments and Hedging Activities Objective and Strategies for Using Derivative Instruments We enter into price hedging arrangements to mitigate effects of commodity price volatility and enhance the predictability of cash flows for a portion of our production. While these instruments mitigate the cash flow risk of future decreases in commodity prices, they may also curtail benefits from future increases in commodity prices. Unsettled Commodity Derivative Instruments As of June 30, 2020 , we had entered into the following crude oil derivative instruments: Swaps Collars Settlement Month Settlement Year Type of Contract Index Bbls Per Day Weighted Average Differential Weighted Average Fixed Price Weighted Average Short Put Price Weighted Average Floor Price Weighted Average Ceiling Price Jul-Sept 2020 Swaps NYMEX WTI 37,500 $ — $ 36.80 $ — $ — $ — Oct-Dec 2020 Swaps NYMEX WTI 14,500 — 51.91 — — — Jul-Dec 2020 Three-Way Collars NYMEX WTI 53,000 — — 10.00 25.00 37.20 Jul-Dec 2020 Sold Calls NYMEX WTI 8,000 — 65.59 — — — Jul-Sept 2020 Basis Swaps Midland (1) 27,000 (4.03 ) — — — — Oct-Dec 2020 Basis Swaps Midland (1) 22,000 (4.21 ) — — — — Jul-Sept 2020 Basis Swaps WTI Roll (2) 78,000 (2.28 ) — — — — Oct-Dec 2020 Basis Swaps WTI Roll (2) 64,000 (2.19 ) — — — — (1) These contracts establish a fixed amount for the differential between pricing in Midland, Texas, and Cushing, Oklahoma. The weighted average differential represents the amount of reduction to Cushing, Oklahoma, prices for the notional volumes covered by the basis swap contracts. (2) Represents the value differential associated with NYMEX West Texas Intermediate (WTI) futures delivery months and prompt month physical delivery. As of June 30, 2020 , we had entered into the following natural gas liquid (NGL) derivative instruments: Swaps Settlement Month Settlement Year Type of Contract Index Bbls per Day Weighted Average Fixed Price Jul 2020 Ethane Swaps Mont Belvieu 6,500 $ 8.39 Aug 2020 Ethane Swaps Mont Belvieu 8,500 8.39 Sept 2020 Ethane Swaps Mont Belvieu 10,500 8.45 Oct-Dec 2020 Ethane Swaps Mont Belvieu 8,500 8.60 Jul-Sept 2020 Propane Swaps Mont Belvieu 5,000 21.04 Jul-Sept 2020 Isobutane Swaps Mont Belvieu 1,000 25.36 Jul-Sept 2020 Butane Swaps Mont Belvieu 1,500 24.31 As of June 30, 2020 , we had entered into the following natural gas derivative instruments: Swaps Collars Settlement Month Settlement Year Type of Contract Index MMBtu Per Day Weighted Average Differential Weighted Average Fixed Price Weighted Average Short Put Price Weighted Average Floor Price Weighted Average Ceiling Price Jul-Dec 2020 Swaps NYMEX HH 90,000 $ — $ 2.60 $ — $ — $ — Jul-Dec 2020 Sold Puts NYMEX HH 90,000 — — 2.15 — — Jul-Oct 2020 Three-Way Collars NYMEX HH 40,000 — — 2.25 2.70 2.85 Jul-Dec 2020 Basis Swaps CIG (1) 139,000 (0.57 ) — — — — Jul-Dec 2020 Basis Swaps WAHA (1) 49,500 (1.05 ) — — — — Jan-Dec 2021 Swaps NYMEX HH 70,000 — 2.42 — — — Jan-Dec 2021 Sold Call Swaptions NYMEX HH 70,000 — 2.42 — — — Jan-Dec 2021 Three-Way Collars NYMEX HH 62,000 — — 1.90 2.40 2.88 Jan-Dec 2021 Basis Swaps CIG (1) 114,000 (0.44 ) — — — — Jan-Dec 2021 Basis Swaps WAHA (1) 32,000 (0.71 ) — — — — Jan-Dec 2021 Swaps ICE TTF (2) 35,000 — 4.15 — — — Jan-Dec 2022 Swaps ICE TTF (2) 49,000 — 4.26 — — — (1) These contracts establish a fixed amount for the differential between index pricing for Colorado Interstate Gas (CIG) and Waha Hub versus NYMEX Henry Hub (HH). The weighted average differential represents the amount of reduction to NYMEX HH prices for the notional volumes covered by the basis swap contracts. (2) In second quarter 2020, we entered into derivative instruments for price hedging protection related to our future production of liquified natural gas (LNG) from our Alen natural gas monetization project, offshore West Africa. The swaps, which were entered into in US dollars per MMBtu, are indexed to ICE Dutch Title Transfer Facility (TTF), an international natural gas benchmark. Fair Value Amounts The fair values of commodity derivative instruments on our consolidated balance sheets were as follows (in millions): Asset Derivative Instruments Liability Derivative Instruments Balance Sheet Location June 30, 2020 December 31, 2019 Balance Sheet Location June 30, 2020 December 31, 2019 Other Current Assets $ 61 $ 14 Other Current Liabilities $ 151 $ 36 Other Noncurrent Assets — 1 Other Noncurrent Liabilities 15 1 Total $ 61 $ 15 $ 166 $ 37 We estimate the fair values of these instruments using published forward commodity price curves as of the date of the estimate. The discount rate used in the discounted cash flow projections is based on published LIBOR rates, Eurodollar futures rates and interest swap rates. The fair values of commodity derivative instruments in an asset position include a measure of counterparty nonperformance risk, and instruments in a liability position include a measure of our own nonperformance risk, each based on the current published credit default swap rates. In addition, for collars, we estimate the values of put options sold and contract floors and ceilings using an option pricing model which considers market volatility, market prices and contract terms. Amounts include the impact of netting clauses within our master agreements that allow us to net cash settle asset and liability positions with the same counterparty. Gains and Losses on Commodity Derivative Instruments The effect of commodity derivative instruments on our consolidated statements of operations and comprehensive loss was as follows: Three Months Ended June 30, Six Months Ended June 30, (millions) 2020 2019 2020 2019 Cash (Received) Paid in Settlement of Commodity Derivative Instruments Crude Oil (1) $ (103 ) $ 7 $ (313 ) $ (2 ) NGL (3 ) — (3 ) — Natural Gas — (8 ) 2 (13 ) Total Cash Received in Settlement of Commodity Derivative Instruments $ (106 ) $ (1 ) $ (314 ) $ (15 ) Non-cash Portion of Loss (Gain) on Commodity Derivative Instruments Crude Oil $ 226 $ (54 ) $ 39 $ 169 NGL 10 — — — Natural Gas 28 (5 ) 44 (2 ) Total Non-cash Portion of Loss (Gain) on Commodity Derivative Instruments $ 264 $ (59 ) $ 83 $ 167 Loss (Gain) on Commodity Derivative Instruments Crude Oil $ 123 $ (47 ) $ (274 ) $ 167 NGL 7 — (3 ) — Natural Gas 28 (13 ) 46 (15 ) Total Loss (Gain) on Commodity Derivative Instruments $ 158 $ (60 ) $ (231 ) $ 152 (1) Six months ended June 30, 2020 includes first quarter 2020 monetization of certain crude oil derivative instruments by settling the instruments prior to their original settlement dates. Additionally, in first quarter 2020 we entered into certain new instruments for the remainder of the year. Certain of this activity was intraperiod and related to crude oil instruments that were not part of our derivative portfolio as of December 31, 2019 and March 31, 2020. Net cash received in first quarter 2020 for these transactions was $160 million

Net Loss Per Share Attributable

Net Loss Per Share Attributable to Noble Energy Common Shareholders	6 Months Ended
	Jun. 30, 2020
Earnings Per Share [Abstract]
Net Loss Per Share Attributable to Noble Energy Common Shareholders	Note 12. Net Loss Per Share Attributable to Noble Energy Common Shareholders Noble Energy's basic loss per share of common stock is computed by dividing net loss attributable to Noble Energy by the weighted average number of shares of Noble Energy common stock outstanding during each period. The following table summarizes the calculation of basic and diluted loss per share: Three Months Ended June 30, Six Months Ended June 30, (millions, except per share amounts) 2020 2019 2020 2019 Net Loss and Comprehensive Loss Attributable to Noble Energy $ (408 ) $ (10 ) $ (4,371 ) $ (323 ) Weighted Average Number of Shares Outstanding, Basic 479 478 480 478 Incremental Shares from Assumed Conversion of Dilutive Stock Options, Restricted Stock, and Shares of Common Stock in Rabbi Trust — — — — Weighted Average Number of Shares Outstanding, Diluted 479 478 480 478 Loss Per Share, Basic and Diluted $ (0.85 ) $ (0.02 ) $ (9.11 ) $ (0.68 ) Number of Antidilutive Stock Options, Shares of Restricted Stock, and Shares of Common Stock in Rabbi Trust Excluded from Calculation Above 16 15 16 15

Basis of Presentation (Policies

Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Presentation	Presentation The accompanying unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the US (US GAAP) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and notes required by US GAAP for complete financial statements. The accompanying consolidated financial statements at June 30, 2020 and December 31, 2019 and for the three and six months ended June 30, 2020 and 2019 contain all normally recurring adjustments considered necessary for a fair presentation of our financial position, results of operations, cash flows and equity for such periods. Certain prior-period amounts have been reclassified to conform to the current period presentation. For the periods presented, net income or loss is materially consistent with comprehensive income or loss. Operating results for the three and six months ended June 30, 2020 are not necessarily indicative of the results that may be expected for the year ending December 31, 2020 . These consolidated financial statements should be read in conjunction with the consolidated financial statements and accompanying notes included in our Annual Report on Form 10-K for the year ended December 31, 2019 .
Consolidation	Consolidation Our consolidated financial statements include our accounts, the accounts of subsidiaries which Noble Energy wholly owns, and the accounts of Noble Midstream Partners LP (Noble Midstream Partners). Noble Energy has determined that the partners with equity at risk in Noble Midstream Partners lack the authority, through voting rights or similar rights, to direct the activities that most significantly impact Noble Midstream Partners' economic performance; therefore, Noble Midstream Partners is considered a variable interest entity. Through Noble Energy's ownership interest in Noble Midstream GP LLC (the General Partner to Noble Midstream Partners), Noble Energy has the authority to direct the activities that most significantly affect economic performance and the obligation to absorb losses or the right to receive benefits that could be potentially significant to Noble Midstream Partners. Therefore, Noble Energy is considered the primary beneficiary and consolidates Noble Midstream Partners. In addition, we use the equity method of accounting for investments in entities that we do not control, but over which we exert significant influence. Amounts recorded within equity method investments, including contributions, include capitalized interest when the primary asset is under construction. All significant intercompany balances and transactions have been eliminated upon consolidation.
Redeemable Noncontrolling Interest	Noncontrolling Interests Our consolidated financial statements include both noncontrolling interests and a redeemable noncontrolling interest. The noncontrolling interests represent the public's ownership in Noble Midstream Partners and third-party ownership in Noble Midstream Partners' consolidated non-wholly owned subsidiaries. Net loss attributable to noncontrolling interests for the six months ended June 30, 2020 includes goodwill impairment expense of $72 million based upon third party ownership interests in the underlying asset. See Note 4. Impairments . The redeemable noncontrolling interest represents perpetual preferred equity with a 6.5% annual dividend rate. Noble Midstream Partners may redeem the preferred equity in whole or in part at any time for cash at a predetermined redemption price. The preferred equity partner can request redemption at a pre-determined base return on or after March 25, 2025.
Estimates	Estimates The preparation of consolidated financial statements in conformity with US GAAP requires us to make a number of estimates and assumptions relating to the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Management evaluates estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic and commodity price environment. The current commodity price, supply and demand environment coupled with the COVID-19 pandemic have increased uncertainty related to our estimates for the six months ended June 30, 2020. Actual results could differ significantly from those estimates.
Revenue Recognition	Revenue Recognition We recognize revenue at an amount that reflects the consideration we expect to be entitled to in exchange for transferring goods or services to a customer. We routinely monitor the credit worthiness of our purchasers. While we maintain credit insurance associated with certain purchasers, we do not carry credit insurance for all purchasers. In the Eastern Mediterranean, we sell natural gas under natural gas sales and purchase agreements (GSPAs) to customers in Israel, Egypt, and Jordan. The majority of these contracts include total contracted quantities for which we will deliver volumes to customers over the life of the agreements. As of June 30, 2020, a total of approximately 9.5 Tcf, gross ( 2.6 Tcf, net), of natural gas remained to be delivered under these contracts. Based on current production levels, our available quantities of proved reserves are more than sufficient to meet delivery commitments associated with these sales agreements with minimal additional capital investment. Certain of our Tamar and Leviathan GSPAs have buyer-minimum take or pay volume-obligations and index prices subject to minimum-price floor supports. In addition, our Egyptian export contracts include provisions which trigger adjustments to either decrease, or increase, fixed minimum take or pay volumes in the event the arithmetic average of daily Brent crude oil prices falls below, or rises above, $50 per barrel for certain periods of time. Our GSPAs do not preclude us from selling natural gas to customers, at amounts which exceed fixed minimum sales volumes.
Recently Issued and Recently Adopted Accounting Standards	Recently Issued Accounting Standards London Interbank Offered Rate (LIBOR) Reform In first quarter 2020, the FASB issued ASU No. 2020-04 (ASU 2020-04): Reference Rate Reform (Topic 848), which provides optional guidance for a limited period of time to ease the transition from LIBOR to an alternative reference rate. The ASU intends to address certain concerns relating to accounting for contract modifications and hedge accounting. These optional expedients and exceptions to applying GAAP, assuming certain criteria are met, are allowed through December 31, 2022. We are currently evaluating the provisions of ASU 2020-04 and have not yet determined whether we will elect the optional expedients. We do not expect the transition to an alternative rate to have a significant impact on our business, operations or liquidity. Recently Adopted Accounting Standards Clarifying Certain Accounting Standards Codification (ASC) Topics In first quarter 2020, the FASB issued ASU No. 2020-01: Investments - Equity Securities (Topic 321), Investments - Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815) , to clarify the interactions between these Topics. The update provides clarifications for entities investing in equity securities accounted for under the ASC 321 measurement alternative and companies that hold certain non-derivative forward contracts and purchased options to acquire equity securities. ASU 2020-01 is effective for fiscal years beginning after December 15, 2020, with early adoption permitted. We early adopted this ASU in first quarter 2020. This adoption did not have a material impact on our financial statements.

Basis of Presentation (Tables)

Basis of Presentation (Tables)	6 Months Ended
	Jun. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of revenue, remaining performance obligation, expected timing of satisfaction	Estimated future net revenues related to remaining performance obligations subject to minimum sales volumes and base pricing as of June 30, 2020 were as follows: (millions) Remainder of 2020 2021 2022 2023 2024 Thereafter Total Natural Gas Revenues $ 298 $ 553 $ 546 $ 550 $ 552 $ 5,192 $ 7,691
Statement of operations information	Other statements of operations information is as follows: Three Months Ended June 30, Six Months Ended June 30, (millions) 2020 2019 2020 2019 Other Revenue Income (Loss) from Equity Method Investments and Other $ 3 $ 16 $ (21 ) $ 33 Midstream Services Revenues – Third Party 26 20 51 44 Total $ 29 $ 36 $ 30 $ 77 Production Expense Lease Operating Expense $ 98 $ 122 $ 236 $ 273 Production and Ad Valorem Taxes 24 41 63 90 Gathering, Transportation and Processing Expense 89 96 184 198 Other Royalty Expense 3 1 7 4 Total $ 214 $ 260 $ 490 $ 565 Exploration Expense Leasehold Impairment (1) $ 3 $ — $ 1,488 $ — Seismic, Staffing Expense and Other 12 33 31 57 Total $ 15 $ 33 $ 1,519 $ 57 Other Operating Expense, Net Finance Lease Right-of-Use Asset Impairment (2) $ — $ — $ 40 $ — Marketing Expense 10 14 19 19 Firm Transportation Exit Cost — — — 92 Corporate Restructuring (3) 30 1 30 1 Other, Net 33 7 28 27 Total $ 73 $ 22 $ 117 $ 139 (1) See Note 4. Impairments and Note 6. Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs . (2) See Note 4. Impairments . (3)
Consolidated balance sheet information	Other balance sheet information is as follows: (millions) June 30, December 31, Accounts Receivable, Net Commodity Sales $ 270 $ 446 Joint Interest Billings 115 164 Other 88 128 Current Expected Credit Losses (8 ) (8 ) Total $ 465 $ 730 Other Current Assets Commodity Derivative Assets $ 61 $ 14 Inventory - Materials and Supplies 68 59 Assets Held for Sale 2 14 Prepaid Expenses and Other Current Assets 83 61 Total $ 214 $ 148 Other Noncurrent Assets Equity Method Investments $ 1,246 $ 1,066 Operating Lease Right-of-Use Assets, Net (1) 225 227 Customer-Related Intangible Assets, Net (2) 262 278 Goodwill (3) — 110 Other Assets, Noncurrent 177 153 Total $ 1,910 $ 1,834 Other Current Liabilities Production and Ad Valorem Taxes $ 109 $ 118 Commodity Derivative Liabilities 151 36 Asset Retirement Obligations 89 84 Interest Payable 59 74 Operating Lease Liabilities 79 88 Compensation and Benefits Payable 53 126 Other Liabilities, Current 166 193 Total $ 706 $ 719 Other Noncurrent Liabilities Deferred Compensation Liabilities $ 121 $ 133 Asset Retirement Obligations 732 730 Operating Lease Liabilities 169 164 Firm Transportation Exit Cost Accrual (4) 113 129 Other Liabilities, Noncurrent 153 222 Total $ 1,288 $ 1,378 (1) Balance includes a five -year $28 million lease renewal executed in first quarter 2020 for a vessel offshore West Africa. (2) Balances at June 30, 2020 and December 31, 2019 are net of accumulated amortization of $78 million and $62 million , respectively. (3) See Note 4. Impairments . (4) Represents the discounted present value of our remaining obligations to third parties for permanent assignments of capacity on pipelines in the Marcellus Shale.
Summary of cash, cash equivalents and restricted cash	We define total cash as cash, cash equivalents and restricted cash. Carrying amounts approximate fair value due to the short-term nature. The following table provides a reconciliation of total cash: Six Months Ended June 30, (millions) 2020 2019 Cash and Cash Equivalents at Beginning of Period $ 484 $ 716 Restricted Cash at Beginning of Period — 3 Cash, Cash Equivalents, and Restricted Cash at Beginning of Period $ 484 $ 719 Cash and Cash Equivalents at End of Period $ 324 $ 470 Restricted Cash at End of Period — 132 Cash, Cash Equivalents, and Restricted Cash at End of Period $ 324 $ 602

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2020
Segment Reporting [Abstract]
Summary of segment information	Oil and Gas Exploration and Production Midstream (millions) Consolidated United States Eastern Mediter-ranean West Africa Other Int'l United States Intersegment Eliminations and Other (1) Corporate Three Months Ended June 30, 2020 Crude Oil Sales $ 261 $ 230 $ — $ 31 $ — $ — $ — $ — NGL Sales 40 40 — — — — — — Natural Gas Sales 192 48 139 5 — — — — Total Crude Oil, NGL and Natural Gas Sales 493 318 139 36 — — — — Sales of Purchased Oil and Gas 49 4 — — — 29 — 16 Income (Loss) from Equity Method Investments and Other 3 (1 ) (1 ) 8 — (3 ) — — Midstream Services Revenues – Third Party 26 — — — — 26 — — Intersegment Revenues — — — — — 92 (92 ) — Total Revenues 571 321 138 44 — 144 (92 ) 16 Lease Operating Expense 98 81 15 20 — (1 ) (17 ) — Production and Ad Valorem Taxes 24 23 — — — 1 — — Gathering, Transportation and Processing Expense 89 133 3 — — 20 (67 ) — Other Royalty Expense 3 3 — — — — — — Total Production Expense 214 240 18 20 — 20 (84 ) — Exploration Expense 15 5 2 5 3 — — — Oil and Gas Exploration and Production Midstream (millions) Consolidated United States Eastern Mediter-ranean West Africa Other Int'l United States Intersegment Eliminations and Other (1) Corporate Depreciation, Depletion and Amortization 320 252 16 22 — 26 (8 ) 12 Cost of Purchased Oil and Gas 63 4 — — — 29 — 30 Asset Impairments 51 — — 51 — — — — Loss on Commodity Derivative Instruments 158 149 — 9 — — — — (Loss) Income Before Income Taxes (476 ) (359 ) 83 (69 ) (6 ) 58 11 (194 ) Additions to Long-Lived Assets, Excluding Acquisitions 106 65 13 19 2 5 (4 ) 6 Additions to Equity Method Investments 3 — — — — 3 — — Three Months Ended June 30, 2019 Crude Oil Sales $ 688 $ 617 $ 2 $ 69 $ — $ — $ — $ — NGL Sales 84 84 — — — — — — Natural Gas Sales 182 72 105 5 — — — — Total Crude Oil, NGL and Natural Gas Sales 954 773 107 74 — — — — Sales of Purchased Oil and Gas 103 28 — — — 52 — 23 Income (Loss) from Equity Method Investments and Other 16 1 — 17 — (2 ) — — Midstream Services Revenues – Third Party 20 — — — — 20 — — Intersegment Revenues — — — — — 91 (91 ) — Total Revenues 1,093 802 107 91 — 161 (91 ) 23 Lease Operating Expense 122 114 9 10 — 1 (12 ) — Production and Ad Valorem Taxes 41 40 — — — 1 — — Gathering, Transportation and Processing Expense 96 124 — — — 31 (59 ) — Other Royalty Expense 1 1 — — — — — — Total Production Expense 260 279 9 10 — 33 (71 ) — Depreciation, Depletion and Amortization 528 457 17 19 — 26 (6 ) 15 Cost of Purchased Oil and Gas 113 28 — — — 48 — 37 Gain on Commodity Derivative Instruments (60 ) (58 ) — (2 ) — — — — Income (Loss) Before Income Taxes 28 70 65 59 (15 ) 46 (15 ) (182 ) Additions to Long-Lived Assets, Excluding Acquisitions 647 478 119 12 2 52 (25 ) 9 Additions to Equity Method Investments 144 — — — — 144 — — Six Months Ended June 30, 2020 Crude Oil Sales $ 839 $ 722 $ 1 $ 116 $ — $ — $ — $ — NGL Sales 102 102 — — — — — — Natural Gas Sales 446 108 329 9 — — — — Oil and Gas Exploration and Production Midstream (millions) Consolidated United States Eastern Mediter-ranean West Africa Other Int'l United States Intersegment Eliminations and Other (1) Corporate Total Crude Oil, NGL and Natural Gas Sales 1,387 932 330 125 — — — — Sales of Purchased Oil and Gas 174 29 — — — 112 — 33 Loss from Equity Method Investments and Other (21 ) (1 ) (3 ) (9 ) — (8 ) — — Midstream Services Revenues – Third Party 51 — — — — 51 — — Intersegment Revenues — — — — — 207 (207 ) — Total Revenues 1,591 960 327 116 — 362 (207 ) 33 Lease Operating Expense 236 189 28 50 — — (31 ) — Production and Ad Valorem Taxes 63 60 — — — 3 — — Gathering, Transportation and Processing Expense 184 279 6 — — 41 (142 ) — Other Royalty Expense 7 7 — — — — — — Total Production Expense 490 535 34 50 — 44 (173 ) — Exploration Expense 1,519 1,499 4 8 8 — — — Depreciation, Depletion and Amortization 812 671 35 46 — 52 (17 ) 25 Cost of Purchased Oil and Gas 202 32 — — — 109 — 61 Asset Impairments 2,754 2,703 — 51 — — — — Goodwill Impairment 110 — — — — 110 — — (Gain) Loss on Commodity Derivative Instruments (231 ) (240 ) — 9 — — — — (Loss) Income Before Income Taxes (4,494 ) (4,276 ) 228 (59 ) (12 ) 27 — (402 ) Additions to Long-Lived Assets, Excluding Acquisitions 548 422 44 38 11 48 (28 ) 13 Additions to Equity Method Investments 155 — — — — 155 — — Six Months Ended June 30, 2019 Crude Oil Sales $ 1,300 $ 1,162 $ 3 $ 135 $ — $ — $ — $ — NGL Sales 180 180 — — — — — — Natural Gas Sales 411 180 222 9 — — — — Total Crude Oil, NGL and Natural Gas Sales 1,891 1,522 225 144 — — — — Sales of Purchased Oil and Gas 177 42 — — — 85 — 50 Income from Equity Method Investments and Other 33 1 — 32 — — — — Midstream Services Revenues – Third Party 44 — — — — 44 — — Intersegment Revenues — — — — — 197 (197 ) — Total Revenues 2,145 1,565 225 176 — 326 (197 ) 50 Lease Operating Expense 273 239 19 34 — 2 (21 ) — Production and Ad Valorem Taxes 90 87 — — — 3 — — Gathering, Transportation and Processing Expense 198 266 — — — 60 (128 ) — Oil and Gas Exploration and Production Midstream (millions) Consolidated United States Eastern Mediter-ranean West Africa Other Int'l United States Intersegment Eliminations and Other (1) Corporate Other Royalty Expense 4 4 — — — — — — Total Production Expense 565 596 19 34 — 65 (149 ) — Depreciation, Depletion and Amortization 1,036 896 33 39 — 51 (13 ) 30 Cost of Purchased Oil and Gas 200 42 — — — 79 — 79 Firm Transportation Exit Cost 92 — — — — — — 92 Loss on Commodity Derivative Instruments 152 130 — 22 — — — — (Loss) Income Before Income Taxes (345 ) (177 ) 149 70 (31 ) 119 (29 ) (446 ) Additions to Long-Lived Assets, Excluding Acquisitions 1,359 990 251 18 12 118 (48 ) 18 Investments in Equity Method Investees 415 — — — — 415 — — June 30, 2020 Property, Plant and Equipment, Net $ 12,986 $ 7,473 $ 3,058 $ 737 $ 55 $ 1,721 $ (222 ) $ 164 December 31, 2019 Property, Plant and Equipment, Net $ 17,451 $ 11,859 $ 3,041 $ 793 $ 44 $ 1,721 $ (223 ) $ 216 (1) Intersegment eliminations related to loss before income taxes are the result of midstream expenditures. Certain of these expenditures are presented as property, plant and equipment within the E&P business on an unconsolidated basis, in accordance with the successful efforts method of accounting. Other expenditures are presented as production expense. Intercompany revenues and expenses are eliminated upon consolidation.

Impairments (Tables)

Impairments (Tables)	6 Months Ended
	Jun. 30, 2020
Other Income and Expenses [Abstract]
Summary of impairment	The effect of impairments on our consolidated statements of operations and comprehensive loss was as follows: Three Months Ended June 30, Six Months Ended June 30, (millions) Statement of Operations Location 2020 2019 2020 2019 Asset Impairment Expense Proved Property Impairment - Delaware Basin Asset Impairments $ — $ — $ 2,703 $ — Capitalized Exploratory Well Costs - Felicita Asset Impairments 51 — 51 — Total Asset Impairment Expense $ 51 $ — $ 2,754 $ — Leasehold Impairment Expense Leasehold Impairment - Delaware Basin Exploration Expense $ — $ — $ 1,385 $ — Leasehold Impairment - Eagle Ford Shale Exploration Expense — — 100 — Leasehold Impairment - Gabon Exploration Expense 3 — 3 — Total Leasehold Impairment Expense $ 3 $ — $ 1,488 $ — Goodwill Impairment - Noble Midstream Partners Goodwill Impairment $ — $ — $ 110 $ — Finance Lease Right-of-Use Asset Impairment Other Operating Expense, Net — — 40 —

Capitalized Exploratory Well _2

Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs (Tables)	6 Months Ended
	Jun. 30, 2020
Extractive Industries [Abstract]
Schedule of changes in capitalized exploratory well costs	Changes in capitalized exploratory well costs are as follows and exclude amounts that were capitalized and subsequently expensed in the same period: (millions) Six Months Ended June 30, 2020 Capitalized Exploratory Well Costs, Beginning of Period $ 280 Additions to Capitalized Exploratory Well Costs Pending Determination of Proved Reserves 15 Capitalized Exploratory Well Costs Charged to Expense (1) (51 ) Capitalized Exploratory Well Costs, End of Period $ 244 (1) Relates to second quarter 2020 impairment of Felicita discovery, Block O, offshore Equatorial Guinea; see Note 2. Basis of Presentation and Note 4. Impairments .
Summary of capitalized well costs	The following table provides an aging of capitalized exploratory well costs based on the date that drilling commenced: (millions, except number of projects) June 30, December 31, Exploratory Well Costs Capitalized for a Period of One Year or Less $ 30 $ 22 Exploratory Well Costs Capitalized for a Period Greater Than One Year Since Commencement of Drilling 214 258 Capitalized Exploratory Well Costs, End of Period $ 244 $ 280 Number of Projects with Exploratory Well Costs That Have Been Capitalized for a Period Greater Than One Year Since Commencement of Drilling 4 5
Schedule of undeveloped lease costs	Changes in undeveloped leasehold costs are as follows: (millions) Six Months Ended June 30, 2020 Undeveloped Leasehold Costs, Beginning of Period $ 2,152 Additions to Undeveloped Leasehold Costs 2 Impairment (1) (1,488 ) Other (2 ) Undeveloped Leasehold Costs, End of Period $ 664 (1) Includes first quarter 2020 impairments of undeveloped leasehold costs for unproved properties in the Delaware Basin and Eagle Ford Shale of $ 1.5 billion collectively and $ 3 million related to our decision not to pursue lease renewal of undeveloped acreage in Gabon. See Note 2. Basis of Presentation and Note 4. Impairments .

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2020
Asset Retirement Obligation Disclosure [Abstract]
Schedule of changes in asset retirement obligations	Changes in ARO are as follows: Six Months Ended June 30, (millions) 2020 2019 Asset Retirement Obligations, Beginning Balance $ 814 $ 880 Liabilities Incurred 19 15 Liabilities Settled (42 ) (56 ) Revisions of Estimates 9 (70 ) Accretion Expense 21 23 Asset Retirement Obligations, Ending Balance $ 821 $ 792

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Schedule of debt	Debt consists of the following: June 30, 2020 December 31, 2019 (millions, except percentages) Debt Interest Rate Debt Interest Rate Noble Energy, Excluding Noble Midstream Partners Revolving Credit Facility, due March 9, 2023 $ 325 1.41 % $ — — % Senior Notes and Debentures 5,884 (1 ) 5,884 (1 ) Finance Lease Obligations 193 — % 205 — % Total Noble Energy Debt, Excluding Noble Midstream Partners Debt 6,402 6,089 Noble Midstream Partners Noble Midstream Services Revolving Credit Facility, due March 9, 2023 735 1.61 % 595 3.11 % Noble Midstream Services Term Loan Credit Facility, due July 31, 2021 500 1.36 % 500 2.85 % Noble Midstream Services Term Loan Credit Facility, due August 23, 2022 400 1.24 % 400 2.74 % Total Noble Midstream Partners Debt 1,635 1,495 Total Debt 8,037 7,584 Net Unamortized Discounts and Debt Issuance Costs (63 ) (65 ) Total Debt, Net of Unamortized Discounts and Debt Issuance Costs 7,974 7,519 Less Amounts Due Within One Year Finance Lease Obligations (38 ) (42 ) Long-Term Debt Due After One Year $ 7,936 $ 7,477 (1) The Senior Notes and Debentures have weighted average interest rates of 4.93% at June 30, 2020 and December 31, 2019 .
Schedule of carrying values and estimated fair values of debt instruments	Fair value information regarding our debt, which excludes finance lease obligations, is as follows: June 30, 2020 December 31, 2019 (millions) Carrying Amount Fair Value Carrying Amount Fair Value Debt $ 7,844 $ 7,529 $ 7,379 $ 8,033

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2020
Income Tax Disclosure [Abstract]
Schedule of income tax provision (benefit)	Income tax (benefit) expense consists of the following: Three Months Ended June 30, Six Months Ended June 30, (millions, except percentages) 2020 2019 2020 2019 Current $ 7 $ 21 $ 44 $ 37 Deferred (96 ) (1 ) (144 ) (101 ) Total Income Tax (Benefit) Expense $ (89 ) $ 20 $ (100 ) $ (64 ) Effective Tax Rate 18.7 % 71.4 % 2.2 % 18.6 %

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	6 Months Ended
	Jun. 30, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of unsettled derivative instruments	As of June 30, 2020 , we had entered into the following crude oil derivative instruments: Swaps Collars Settlement Month Settlement Year Type of Contract Index Bbls Per Day Weighted Average Differential Weighted Average Fixed Price Weighted Average Short Put Price Weighted Average Floor Price Weighted Average Ceiling Price Jul-Sept 2020 Swaps NYMEX WTI 37,500 $ — $ 36.80 $ — $ — $ — Oct-Dec 2020 Swaps NYMEX WTI 14,500 — 51.91 — — — Jul-Dec 2020 Three-Way Collars NYMEX WTI 53,000 — — 10.00 25.00 37.20 Jul-Dec 2020 Sold Calls NYMEX WTI 8,000 — 65.59 — — — Jul-Sept 2020 Basis Swaps Midland (1) 27,000 (4.03 ) — — — — Oct-Dec 2020 Basis Swaps Midland (1) 22,000 (4.21 ) — — — — Jul-Sept 2020 Basis Swaps WTI Roll (2) 78,000 (2.28 ) — — — — Oct-Dec 2020 Basis Swaps WTI Roll (2) 64,000 (2.19 ) — — — — (1) These contracts establish a fixed amount for the differential between pricing in Midland, Texas, and Cushing, Oklahoma. The weighted average differential represents the amount of reduction to Cushing, Oklahoma, prices for the notional volumes covered by the basis swap contracts. (2) Represents the value differential associated with NYMEX West Texas Intermediate (WTI) futures delivery months and prompt month physical delivery. As of June 30, 2020 , we had entered into the following natural gas liquid (NGL) derivative instruments: Swaps Settlement Month Settlement Year Type of Contract Index Bbls per Day Weighted Average Fixed Price Jul 2020 Ethane Swaps Mont Belvieu 6,500 $ 8.39 Aug 2020 Ethane Swaps Mont Belvieu 8,500 8.39 Sept 2020 Ethane Swaps Mont Belvieu 10,500 8.45 Oct-Dec 2020 Ethane Swaps Mont Belvieu 8,500 8.60 Jul-Sept 2020 Propane Swaps Mont Belvieu 5,000 21.04 Jul-Sept 2020 Isobutane Swaps Mont Belvieu 1,000 25.36 Jul-Sept 2020 Butane Swaps Mont Belvieu 1,500 24.31 As of June 30, 2020 , we had entered into the following natural gas derivative instruments: Swaps Collars Settlement Month Settlement Year Type of Contract Index MMBtu Per Day Weighted Average Differential Weighted Average Fixed Price Weighted Average Short Put Price Weighted Average Floor Price Weighted Average Ceiling Price Jul-Dec 2020 Swaps NYMEX HH 90,000 $ — $ 2.60 $ — $ — $ — Jul-Dec 2020 Sold Puts NYMEX HH 90,000 — — 2.15 — — Jul-Oct 2020 Three-Way Collars NYMEX HH 40,000 — — 2.25 2.70 2.85 Jul-Dec 2020 Basis Swaps CIG (1) 139,000 (0.57 ) — — — — Jul-Dec 2020 Basis Swaps WAHA (1) 49,500 (1.05 ) — — — — Jan-Dec 2021 Swaps NYMEX HH 70,000 — 2.42 — — — Jan-Dec 2021 Sold Call Swaptions NYMEX HH 70,000 — 2.42 — — — Jan-Dec 2021 Three-Way Collars NYMEX HH 62,000 — — 1.90 2.40 2.88 Jan-Dec 2021 Basis Swaps CIG (1) 114,000 (0.44 ) — — — — Jan-Dec 2021 Basis Swaps WAHA (1) 32,000 (0.71 ) — — — — Jan-Dec 2021 Swaps ICE TTF (2) 35,000 — 4.15 — — — Jan-Dec 2022 Swaps ICE TTF (2) 49,000 — 4.26 — — — (1) These contracts establish a fixed amount for the differential between index pricing for Colorado Interstate Gas (CIG) and Waha Hub versus NYMEX Henry Hub (HH). The weighted average differential represents the amount of reduction to NYMEX HH prices for the notional volumes covered by the basis swap contracts. (2) In second quarter 2020, we entered into derivative instruments for price hedging protection related to our future production of liquified natural gas (LNG) from our Alen natural gas monetization project, offshore West Africa. The swaps, which were entered into in US dollars per MMBtu, are indexed to ICE Dutch Title Transfer Facility (TTF), an international natural gas benchmark.
Summary of fair value of derivative instruments	The fair values of commodity derivative instruments on our consolidated balance sheets were as follows (in millions): Asset Derivative Instruments Liability Derivative Instruments Balance Sheet Location June 30, 2020 December 31, 2019 Balance Sheet Location June 30, 2020 December 31, 2019 Other Current Assets $ 61 $ 14 Other Current Liabilities $ 151 $ 36 Other Noncurrent Assets — 1 Other Noncurrent Liabilities 15 1 Total $ 61 $ 15 $ 166 $ 37
Schedule of derivative instruments, (gain) loss	The effect of commodity derivative instruments on our consolidated statements of operations and comprehensive loss was as follows: Three Months Ended June 30, Six Months Ended June 30, (millions) 2020 2019 2020 2019 Cash (Received) Paid in Settlement of Commodity Derivative Instruments Crude Oil (1) $ (103 ) $ 7 $ (313 ) $ (2 ) NGL (3 ) — (3 ) — Natural Gas — (8 ) 2 (13 ) Total Cash Received in Settlement of Commodity Derivative Instruments $ (106 ) $ (1 ) $ (314 ) $ (15 ) Non-cash Portion of Loss (Gain) on Commodity Derivative Instruments Crude Oil $ 226 $ (54 ) $ 39 $ 169 NGL 10 — — — Natural Gas 28 (5 ) 44 (2 ) Total Non-cash Portion of Loss (Gain) on Commodity Derivative Instruments $ 264 $ (59 ) $ 83 $ 167 Loss (Gain) on Commodity Derivative Instruments Crude Oil $ 123 $ (47 ) $ (274 ) $ 167 NGL 7 — (3 ) — Natural Gas 28 (13 ) 46 (15 ) Total Loss (Gain) on Commodity Derivative Instruments $ 158 $ (60 ) $ (231 ) $ 152 (1) Six months ended June 30, 2020 includes first quarter 2020 monetization of certain crude oil derivative instruments by settling the instruments prior to their original settlement dates. Additionally, in first quarter 2020 we entered into certain new instruments for the remainder of the year. Certain of this activity was intraperiod and related to crude oil instruments that were not part of our derivative portfolio as of December 31, 2019 and March 31, 2020. Net cash received in first quarter 2020 for these transactions was $160 million .

Net Loss Per Share Attributab_2

Net Loss Per Share Attributable to Noble Energy Common Shareholders (Tables)	6 Months Ended
	Jun. 30, 2020
Earnings Per Share [Abstract]
Schedule of earnings per share	The following table summarizes the calculation of basic and diluted loss per share: Three Months Ended June 30, Six Months Ended June 30, (millions, except per share amounts) 2020 2019 2020 2019 Net Loss and Comprehensive Loss Attributable to Noble Energy $ (408 ) $ (10 ) $ (4,371 ) $ (323 ) Weighted Average Number of Shares Outstanding, Basic 479 478 480 478 Incremental Shares from Assumed Conversion of Dilutive Stock Options, Restricted Stock, and Shares of Common Stock in Rabbi Trust — — — — Weighted Average Number of Shares Outstanding, Diluted 479 478 480 478 Loss Per Share, Basic and Diluted $ (0.85 ) $ (0.02 ) $ (9.11 ) $ (0.68 ) Number of Antidilutive Stock Options, Shares of Restricted Stock, and Shares of Common Stock in Rabbi Trust Excluded from Calculation Above 16 15 16 15

Organization and Nature of Op_2

Organization and Nature of Operations (Details) - Subsequent Event - Chevron - Noble Energy - Forecast - USD ($) $ / shares in Units, $ in Billions	3 Months Ended
	Dec. 31, 2020	Jul. 20, 2020
Business Acquisition
Shares issues as consideration (shares)	$ 13
Share price (usd per share)		$ 10.38
Share conversion rate (per share)		$ 0.1191

Basis of Presentation - Noncont

Basis of Presentation - Noncontrolling Interest (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Accumulated Other Comprehensive Income (Loss) [Line Items]
Goodwill impairment	$ 0	$ 0	$ 110	$ 0
Preferred stock dividend rate			6.50%
Non-controlling Interests
Accumulated Other Comprehensive Income (Loss) [Line Items]
Goodwill impairment			$ 72

Basis of Presentation - Perform

Basis of Presentation - Performance Obligation, Expected Timing (Details)	Jun. 30, 2020USD ($)MMcfTcf
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Gross undelivered natural gas contracts (tcf) | Tcf	9.5
Net undelivered natural gas contracts (tcf) | Tcf	2.6
Price per barrel which trigger provision adjustments	$ 50
Increase in minimum volume commitments (MMcf/d) | MMcf	650
Increase in contractual minimum volumes (MMcf/d) | MMcf	450
Natural gas revenues	$ 7,691,000,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-07-01
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Natural gas revenues	$ 298,000,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Natural gas revenues	$ 553,000,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Natural gas revenues	$ 546,000,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Natural gas revenues	$ 550,000,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Natural gas revenues	$ 552,000,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Natural gas revenues	$ 5,192,000,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing

Basis of Presentation - Stateme

Basis of Presentation - Statements of Operations Information (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Other Revenue
Revenue from sales	$ 571	$ 1,093	$ 1,591	$ 2,145
Production Expense
Lease Operating Expense	98	122	236	273
Production and Ad Valorem Taxes	24	41	63	90
Gathering, Transportation and Processing Expense	89	96	184	198
Total	214	260	490	565
Exploration Expense
Leasehold impairment	3	0	1,488	0
Seismic, Staffing Expense and Other	12	33	31	57
Total	15	33	1,519	57
Other Operating Expense, Net
Finance lease right-of use asset impairment	0	0	40	0
Marketing Expense	10	14	19	19
Firm Transportation Exit Cost	0	0	0	92
Corporate Restructuring	30	1	30	1
Other, Net	33	7	28	27
Total	73	22	117	139
Other Revenue
Other Revenue
Revenue from sales	29	36	30	77
Income (Loss) from Equity Method Investments and Other
Other Revenue
Revenue from sales	3	16	(21)	33
Midstream Services Revenues – Third Party
Other Revenue
Revenue from sales	26	20	51	44
Other Royalty Expense
Production Expense
Other Royalty Expense	$ 3	$ 1	$ 7	$ 4

Basis of Presentation - Balance

Basis of Presentation - Balance Sheet Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Jun. 30, 2020	Dec. 31, 2019
Accounts Receivable, Net
Commodity Sales		$ 270	$ 446
Joint Interest Billings		115	164
Other		88	128
Current Expected Credit Losses		(8)	(8)
Total		465	730
Other Current Assets
Commodity Derivative Assets		61	14
Inventory - Materials and Supplies		68	59
Assets held for sale		2	14
Prepaid Expenses and Other Current Assets		83	61
Total		214	148
Other Noncurrent Assets
Equity Method Investments		1,246	1,066
Operating lease right of use assets		225	227
Customer-related intangible assets, net		262	278
Goodwill		0	110
Other Assets, Noncurrent		177	153
Total		1,910	1,834
Other Current Liabilities
Production and Ad Valorem Taxes		109	118
Commodity Derivative Liabilities		151	36
Asset Retirement Obligations		89	84
Interest Payable		59	74
Operating Lease Liabilities		79	88
Compensation and Benefits Payable		53	126
Other Liabilities, Current		166	193
Total		706	719
Other Noncurrent Liabilities
Deferred Compensation Liabilities		121	133
Asset Retirement Obligations		732	730
Operating Lease Liabilities		169	164
Firm transportation exit cost accrual		113	129
Other Liabilities, Noncurrent		153	222
Total		1,288	1,378
Lease renewal term	5 years
Lease renewal	$ 28
Accumulated amortization		$ 78	$ 62
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]		us-gaap:OtherAssetsNoncurrent	us-gaap:OtherAssetsNoncurrent
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]		us-gaap:OtherLiabilitiesCurrent	us-gaap:OtherLiabilitiesCurrent
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]		us-gaap:OtherLiabilitiesNoncurrent	us-gaap:OtherLiabilitiesNoncurrent

Basis of Presentation - Compone

Basis of Presentation - Components of Cash, Cash Equivalents and Restricted Cash (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019	Jun. 30, 2019	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Cash and cash equivalents	$ 324	$ 484	$ 470	$ 716
Restricted cash	0	0	132	3
Cash, cash equivalents, and restricted cash	$ 324	$ 484	$ 602	$ 719

Segment Information - Operating

Segment Information - Operating Results by Segment (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Segment Reporting Information
Revenue from sales	$ 571	$ 1,093	$ 1,591	$ 2,145
Lease Operating Expense	98	122	236	273
Production and Ad Valorem Taxes	24	41	63	90
Gathering, Transportation and Processing Expense	89	96	184	198
Asset Impairments	51	0	2,754	0
Total	214	260	490	565
Exploration Expense	15	33	1,519	57
Depreciation, Depletion and Amortization	320	528	812	1,036
Asset Impairments	51
Goodwill Impairment	0	0	110	0
Firm Transportation Exit Cost				92
(Gain) Loss on Commodity Derivative Instruments	158	(60)	(231)	152
Income (Loss) Before Income Taxes	(476)	28	(4,494)	(345)
Additions to Long-Lived Assets, Excluding Acquisitions	106	647	548	1,359
Additions to Equity Method Investments	3	144	155
Property, Plant and Equipment, Net	12,986		12,986		$ 17,451
Equity Method Investment, Nonconsolidated Investee or Group of Investees
Segment Reporting Information
Revenue from sales				415
Operating Segments | Equity Method Investment, Nonconsolidated Investee or Group of Investees
Segment Reporting Information
Revenue from sales				415
Intersegment Eliminations and Other
Segment Reporting Information
Revenue from sales	(92)	(91)	(207)	(197)
Lease Operating Expense	(17)	(12)	(31)	(21)
Production and Ad Valorem Taxes	0	0	0	0
Gathering, Transportation and Processing Expense	(67)	(59)	(142)	(128)
Asset Impairments			0
Total	(84)	(71)	(173)	(149)
Exploration Expense	0		0
Depreciation, Depletion and Amortization	(8)	(6)	(17)	(13)
Asset Impairments	0
(Gain) Loss on Commodity Derivative Instruments	0	0	0	0
Income (Loss) Before Income Taxes	11	(15)	0	(29)
Additions to Long-Lived Assets, Excluding Acquisitions	(4)	(25)	(28)	(48)
Additions to Equity Method Investments	0	0	0
Property, Plant and Equipment, Net	(222)		(222)		(223)
Corporate
Segment Reporting Information
Revenue from sales	16	23	33	50
Lease Operating Expense	0	0	0	0
Production and Ad Valorem Taxes	0	0	0	0
Gathering, Transportation and Processing Expense	0	0	0	0
Asset Impairments			0
Total	0	0	0	0
Exploration Expense	0		0
Depreciation, Depletion and Amortization	12	15	25	30
Asset Impairments	0
Firm Transportation Exit Cost				92
(Gain) Loss on Commodity Derivative Instruments	0	0	0	0
Income (Loss) Before Income Taxes	(194)	(182)	(402)	(446)
Additions to Long-Lived Assets, Excluding Acquisitions	6	9	13	18
Additions to Equity Method Investments	0	0	0
Property, Plant and Equipment, Net	164		164		216
United States | Operating Segments
Segment Reporting Information
Revenue from sales	321	802	960	1,565
Lease Operating Expense	81	114	189	239
Production and Ad Valorem Taxes	23	40	60	87
Gathering, Transportation and Processing Expense	133	124	279	266
Asset Impairments			2,703
Total	240	279	535	596
Exploration Expense	5		1,499
Depreciation, Depletion and Amortization	252	457	671	896
Asset Impairments	0
(Gain) Loss on Commodity Derivative Instruments	149	(58)	(240)	130
Income (Loss) Before Income Taxes	(359)	70	(4,276)	(177)
Additions to Long-Lived Assets, Excluding Acquisitions	65	478	422	990
Additions to Equity Method Investments	0	0	0
Property, Plant and Equipment, Net	7,473		7,473		11,859
Eastern Mediter-ranean | Operating Segments
Segment Reporting Information
Revenue from sales	138	107	327	225
Lease Operating Expense	15	9	28	19
Production and Ad Valorem Taxes	0	0	0	0
Gathering, Transportation and Processing Expense	3	0	6	0
Asset Impairments			0
Total	18	9	34	19
Exploration Expense	2		4
Depreciation, Depletion and Amortization	16	17	35	33
Asset Impairments	0
(Gain) Loss on Commodity Derivative Instruments	0	0	0	0
Income (Loss) Before Income Taxes	83	65	228	149
Additions to Long-Lived Assets, Excluding Acquisitions	13	119	44	251
Additions to Equity Method Investments	0	0	0
Property, Plant and Equipment, Net	3,058		3,058		3,041
West Africa | Operating Segments
Segment Reporting Information
Revenue from sales	44	91	116	176
Lease Operating Expense	20	10	50	34
Production and Ad Valorem Taxes	0	0	0	0
Gathering, Transportation and Processing Expense	0	0	0	0
Asset Impairments			51
Total	20	10	50	34
Exploration Expense	5		8
Depreciation, Depletion and Amortization	22	19	46	39
Asset Impairments	51
(Gain) Loss on Commodity Derivative Instruments	9	(2)	9	22
Income (Loss) Before Income Taxes	(69)	59	(59)	70
Additions to Long-Lived Assets, Excluding Acquisitions	19	12	38	18
Additions to Equity Method Investments	0	0	0
Property, Plant and Equipment, Net	737		737		793
Other Int'l | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Lease Operating Expense	0	0	0	0
Production and Ad Valorem Taxes	0	0	0	0
Gathering, Transportation and Processing Expense	0	0	0	0
Asset Impairments			0
Total	0	0	0	0
Exploration Expense	3		8
Depreciation, Depletion and Amortization	0	0	0	0
Asset Impairments	0
(Gain) Loss on Commodity Derivative Instruments	0	0	0	0
Income (Loss) Before Income Taxes	(6)	(15)	(12)	(31)
Additions to Long-Lived Assets, Excluding Acquisitions	2	2	11	12
Additions to Equity Method Investments	0	0	0
Property, Plant and Equipment, Net	55		55		44
Midstream | Operating Segments
Segment Reporting Information
Revenue from sales	144	161	362	326
Lease Operating Expense	(1)	1	0	2
Production and Ad Valorem Taxes	1	1	3	3
Gathering, Transportation and Processing Expense	20	31	41	60
Asset Impairments			0
Total	20	33	44	65
Exploration Expense	0		0
Depreciation, Depletion and Amortization	26	26	52	51
Asset Impairments	0
Goodwill Impairment			110
(Gain) Loss on Commodity Derivative Instruments	0	0	0	0
Income (Loss) Before Income Taxes	58	46	27	119
Additions to Long-Lived Assets, Excluding Acquisitions	5	52	48	118
Additions to Equity Method Investments	3	144	155
Property, Plant and Equipment, Net	1,721		1,721		$ 1,721
Midstream | Intersegment Eliminations and Other
Segment Reporting Information
Revenue from sales	92	91	207	197
Total Crude Oil, NGL and Natural Gas Sales
Segment Reporting Information
Revenue from sales	493	954	1,387	1,891
Total Crude Oil, NGL and Natural Gas Sales | Intersegment Eliminations and Other
Segment Reporting Information
Revenue from sales	0	0	0	0
Total Crude Oil, NGL and Natural Gas Sales | Corporate
Segment Reporting Information
Revenue from sales	0	0	0	0
Total Crude Oil, NGL and Natural Gas Sales | United States | Operating Segments
Segment Reporting Information
Revenue from sales	318	773	932	1,522
Total Crude Oil, NGL and Natural Gas Sales | Eastern Mediter-ranean | Operating Segments
Segment Reporting Information
Revenue from sales	139	107	330	225
Total Crude Oil, NGL and Natural Gas Sales | West Africa | Operating Segments
Segment Reporting Information
Revenue from sales	36	74	125	144
Total Crude Oil, NGL and Natural Gas Sales | Other Int'l | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Total Crude Oil, NGL and Natural Gas Sales | Midstream | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Crude Oil Sales
Segment Reporting Information
Revenue from sales	261	688	839	1,300
Crude Oil Sales | Intersegment Eliminations and Other
Segment Reporting Information
Revenue from sales	0	0	0	0
Crude Oil Sales | Corporate
Segment Reporting Information
Revenue from sales	0	0	0	0
Crude Oil Sales | United States | Operating Segments
Segment Reporting Information
Revenue from sales	230	617	722	1,162
Crude Oil Sales | Eastern Mediter-ranean | Operating Segments
Segment Reporting Information
Revenue from sales	0	2	1	3
Crude Oil Sales | West Africa | Operating Segments
Segment Reporting Information
Revenue from sales	31	69	116	135
Crude Oil Sales | Other Int'l | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Crude Oil Sales | Midstream | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
NGL Sales
Segment Reporting Information
Revenue from sales	40	84	102	180
NGL Sales | Intersegment Eliminations and Other
Segment Reporting Information
Revenue from sales	0	0	0	0
NGL Sales | Corporate
Segment Reporting Information
Revenue from sales	0	0	0	0
NGL Sales | United States | Operating Segments
Segment Reporting Information
Revenue from sales	40	84	102	180
NGL Sales | Eastern Mediter-ranean | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
NGL Sales | West Africa | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
NGL Sales | Other Int'l | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
NGL Sales | Midstream | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Natural Gas Sales
Segment Reporting Information
Revenue from sales	192	182	446	411
Natural Gas Sales | Intersegment Eliminations and Other
Segment Reporting Information
Revenue from sales	0	0	0	0
Natural Gas Sales | Corporate
Segment Reporting Information
Revenue from sales	0	0	0	0
Natural Gas Sales | United States | Operating Segments
Segment Reporting Information
Revenue from sales	48	72	108	180
Natural Gas Sales | Eastern Mediter-ranean | Operating Segments
Segment Reporting Information
Revenue from sales	139	105	329	222
Natural Gas Sales | West Africa | Operating Segments
Segment Reporting Information
Revenue from sales	5	5	9	9
Natural Gas Sales | Other Int'l | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Natural Gas Sales | Midstream | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Sales of Purchased Oil and Gas
Segment Reporting Information
Revenue from sales	49	103	174	177
Other Royalty Expense	63	113	202	200
Sales of Purchased Oil and Gas | Intersegment Eliminations and Other
Segment Reporting Information
Revenue from sales	0	0	0	0
Other Royalty Expense	0	0
Sales of Purchased Oil and Gas | Corporate
Segment Reporting Information
Revenue from sales	16	23	33	50
Other Royalty Expense	30	37
Sales of Purchased Oil and Gas | United States | Operating Segments
Segment Reporting Information
Revenue from sales	4	28	29	42
Other Royalty Expense	4	28
Sales of Purchased Oil and Gas | Eastern Mediter-ranean | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Other Royalty Expense	0	0
Sales of Purchased Oil and Gas | West Africa | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Other Royalty Expense	0	0
Sales of Purchased Oil and Gas | Other Int'l | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Other Royalty Expense	0	0
Sales of Purchased Oil and Gas | Midstream | Operating Segments
Segment Reporting Information
Revenue from sales	29	52	112	85
Other Royalty Expense	29	48
(Loss) Income from Equity Method Investments and Other
Segment Reporting Information
Revenue from sales	3	16	(21)	33
(Loss) Income from Equity Method Investments and Other | Intersegment Eliminations and Other
Segment Reporting Information
Revenue from sales	0	0	0	0
(Loss) Income from Equity Method Investments and Other | Corporate
Segment Reporting Information
Revenue from sales	0	0	0	0
(Loss) Income from Equity Method Investments and Other | United States | Operating Segments
Segment Reporting Information
Revenue from sales	(1)	1	(1)	1
(Loss) Income from Equity Method Investments and Other | Eastern Mediter-ranean | Operating Segments
Segment Reporting Information
Revenue from sales	(1)	0	(3)	0
(Loss) Income from Equity Method Investments and Other | West Africa | Operating Segments
Segment Reporting Information
Revenue from sales	8	17	(9)	32
(Loss) Income from Equity Method Investments and Other | Other Int'l | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
(Loss) Income from Equity Method Investments and Other | Midstream | Operating Segments
Segment Reporting Information
Revenue from sales	(3)	(2)	(8)	0
Midstream Services Revenues – Third Party
Segment Reporting Information
Revenue from sales	26	20	51	44
Midstream Services Revenues – Third Party | Intersegment Eliminations and Other
Segment Reporting Information
Revenue from sales	0	0	0	0
Midstream Services Revenues – Third Party | Corporate
Segment Reporting Information
Revenue from sales	0	0	0	0
Midstream Services Revenues – Third Party | United States | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Midstream Services Revenues – Third Party | Eastern Mediter-ranean | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Midstream Services Revenues – Third Party | West Africa | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Midstream Services Revenues – Third Party | Other Int'l | Operating Segments
Segment Reporting Information
Revenue from sales	0	0	0	0
Midstream Services Revenues – Third Party | Midstream | Operating Segments
Segment Reporting Information
Revenue from sales	26	20	51	44
Other Royalty Expense
Segment Reporting Information
Other Royalty Expense	3	1	7	4
Other Royalty Expense | Intersegment Eliminations and Other
Segment Reporting Information
Other Royalty Expense	0	0	0	0
Other Royalty Expense | Corporate
Segment Reporting Information
Other Royalty Expense	0	0	0	0
Other Royalty Expense | United States | Operating Segments
Segment Reporting Information
Other Royalty Expense	3	1	7	4
Other Royalty Expense | Eastern Mediter-ranean | Operating Segments
Segment Reporting Information
Other Royalty Expense	0	0	0	0
Other Royalty Expense | West Africa | Operating Segments
Segment Reporting Information
Other Royalty Expense	0	0	0	0
Other Royalty Expense | Other Int'l | Operating Segments
Segment Reporting Information
Other Royalty Expense	0	0	0	0
Other Royalty Expense | Midstream | Operating Segments
Segment Reporting Information
Other Royalty Expense	$ 0	$ 0	0	0
Cost of Purchased Oil and Gas
Segment Reporting Information
Other Royalty Expense			202	200
Cost of Purchased Oil and Gas | Intersegment Eliminations and Other
Segment Reporting Information
Other Royalty Expense			0	0
Cost of Purchased Oil and Gas | Corporate
Segment Reporting Information
Other Royalty Expense			61	79
Cost of Purchased Oil and Gas | United States | Operating Segments
Segment Reporting Information
Other Royalty Expense			32	42
Cost of Purchased Oil and Gas | Eastern Mediter-ranean | Operating Segments
Segment Reporting Information
Other Royalty Expense			0	0
Cost of Purchased Oil and Gas | West Africa | Operating Segments
Segment Reporting Information
Other Royalty Expense			0	0
Cost of Purchased Oil and Gas | Other Int'l | Operating Segments
Segment Reporting Information
Other Royalty Expense			0	0
Cost of Purchased Oil and Gas | Midstream | Operating Segments
Segment Reporting Information
Other Royalty Expense			$ 109	$ 79

Impairments (Details)

Impairments (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Mar. 31, 2010
Property, Plant and Equipment
Asset impairments expenses	$ 51		$ 0	$ 2,754	$ 0
Leasehold impairment expense	51
Goodwill impairment	0		0	110	0
Finance lease right-of use asset impairment	0		0	40	0
Carrying Amount
Property, Plant and Equipment
Finance Leases		$ 88
Leasehold Impairment
Property, Plant and Equipment
Leasehold impairment expense	3		0	1,488	0
Delaware Basin | Proved Property
Property, Plant and Equipment
Asset impairments expenses	0		0	2,703	0
Felicita
Property, Plant and Equipment
Asset impairments expenses	51		0	51	0
Delaware Basin | Leasehold Impairment
Property, Plant and Equipment
Leasehold impairment expense	0		0	1,385	0
Fair value of proved properties		910				$ 3,600
Fair value of unproved properties		530				$ 1,900
Asset impairment charges		4,100
Eagle Ford Shale | Leasehold Impairment
Property, Plant and Equipment
Leasehold impairment expense	0		0	100	0
Gabon | Leasehold Impairment
Property, Plant and Equipment
Leasehold impairment expense			0	3	0
Non-controlling Interests
Property, Plant and Equipment
Leasehold impairment expense				72
Goodwill impairment				72
Parent Company
Property, Plant and Equipment
Leasehold impairment expense				38
Noble Midstream Partners
Property, Plant and Equipment
Goodwill impairment	0	110	0	110	0
Finance Lease Right-of-Use Asset Impairment
Property, Plant and Equipment
Finance lease right-of use asset impairment	$ 0	$ 40	$ 0	$ 40	$ 0

Acquisitions, Divestitures an_2

Acquisitions, Divestitures and Equity Method Investments - Narrative (Details) $ in Millions	1 Months Ended		3 Months Ended	6 Months Ended
	Feb. 29, 2020USD ($)	Feb. 28, 2019USD ($)aMMBbls	Jun. 30, 2019USD ($)	Jun. 30, 2020USD ($)	Jun. 30, 2019USD ($)	Dec. 31, 2019USD ($)	Mar. 31, 2019USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Payments to acquire equity method investments				$ 228	$ 415
Cash consideration				1,246		$ 1,066
Disposed by sale | Reeves County Assets
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proved and unproved non-core acreage sold (in acres) | a		13,000
Proceeds from divestitures		$ 131
Saddlehorn Pipeline Company, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Equity method investment, ownership interest (percent)	20.00%
Payments to acquire equity method investments	$ 160
Saddlehorn Pipeline Company, LLC | Noble Midstream
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Payments to acquire equity method investments	$ 87
EPIC Y-Grade, LP
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Payments to acquire equity method investments				14
Equity interest in acquiree (percent)							15.00%
EPIC Y-Grade, LP | Noble Midstream
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Contributions to equity method investments			$ 28
Cash consideration							$ 227
EPIC Crude Holdings, LP
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Payments to acquire equity method investments				33
Equity interest in acquiree (percent)							30.00%
EPIC Crude Holdings, LP | Noble Midstream
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Contributions to equity method investments			$ 114
EPIC Propane
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Payments to acquire equity method investments				4
Delaware Crossing JV
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Contributions to equity method investments				17
Delaware Crossing JV | Noble Midstream
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Equity method investment, ownership interest (percent)		5000.00%
Payments to acquire equity method investments				$ 39
Pipeline capacity (in MBbl/d) | MMBbls		160
Delaware Crossing JV | Salt Creek Midstream LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Equity method investment, ownership interest (percent)		5000.00%
Black Diamond Gathering | Black Diamond Gathering LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Ownership interest (percent)	54.40%

Capitalized Exploratory Well _3

Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs - Changes in Capitalized Exploratory Well Costs (Details) $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)
Capitalized Exploratory Well Costs
Capitalized Exploratory Well Costs, Beginning of Period	$ 280
Additions to Capitalized Exploratory Well Costs Pending Determination of Proved Reserves	15
Capitalized Exploratory Well Costs Charged to Expense	(51)
Capitalized Exploratory Well Costs, End of Period	$ 244

Capitalized Exploratory Well _4

Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs - Aging of Capitalized Exploratory Well Costs (Details) $ in Millions	Jun. 30, 2020USD ($)project	Dec. 31, 2019USD ($)project
Extractive Industries [Abstract]
Exploratory Well Costs Capitalized for a Period of One Year or Less	$ 30	$ 22
Exploratory Well Costs Capitalized for a Period Greater Than One Year Since Commencement of Drilling	214	258
Capitalized Exploratory Well Costs, End of Period	$ 244	$ 280
Number of Projects with Exploratory Well Costs That Have Been Capitalized for a Period Greater Than One Year Since Commencement of Drilling | project	4	5

Capitalized Exploratory Well _5

Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs - Rollforward of Undeveloped Leasehold Costs (Details) $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)
Proved Developed and Undeveloped Reserves
Undeveloped Leasehold Costs, Beginning of Period	$ 2,152
Additions to Undeveloped Leasehold Costs	2
Impairment	(1,488)
Other	(2)
Undeveloped Leasehold Costs, End of Period	$ 664

Capitalized Exploratory Well _6

Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Mar. 31, 2020	Jun. 30, 2020
Projects with Exploratory Well Costs Capitalized for More than One Year Since The Commencement of Drilling
Impairment		$ 1,488
Delaware Basin
Projects with Exploratory Well Costs Capitalized for More than One Year Since The Commencement of Drilling
Capitalized undeveloped leasehold cost		530
Other US Onshore Properties
Projects with Exploratory Well Costs Capitalized for More than One Year Since The Commencement of Drilling
Capitalized undeveloped leasehold cost		80
Other Int'l
Projects with Exploratory Well Costs Capitalized for More than One Year Since The Commencement of Drilling
Capitalized undeveloped leasehold cost		$ 54
Delaware Basin And Eagle Ford Shale
Projects with Exploratory Well Costs Capitalized for More than One Year Since The Commencement of Drilling
Impairment	$ 1,500
Gabon
Projects with Exploratory Well Costs Capitalized for More than One Year Since The Commencement of Drilling
Impairment	$ 3

Asset Retirement Obligations -

Asset Retirement Obligations - ARO Activity (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Asset Retirement Obligation, Roll Forward Analysis
Asset Retirement Obligations, Beginning Balance	$ 814	$ 880
Liabilities Incurred	19	15
Liabilities Settled	(42)	(56)
Revisions of Estimates	9	(70)
Accretion Expense	21	23
Asset Retirement Obligations, Ending Balance	$ 821	$ 792

Asset Retirement Obligations _2

Asset Retirement Obligations - Narrative (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Reserve Quantities
Liabilities settled	$ 42	$ 56
DJ Basin
Reserve Quantities
Liabilities settled	$ 35	$ 73

Debt - Summary of Debt (Details

Debt - Summary of Debt (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Debt Instrument
Total Debt	$ 8,037	$ 7,584
Net Unamortized Discounts and Debt Issuance Costs	(63)	(65)
Total debt	7,974	7,519
Finance Lease Obligations	(38)	(42)
Long-Term Debt Due After One Year	$ 7,936	$ 7,477
Finance Lease, Liability, Statement of Financial Position [Extensible List]	us-gaap:LongTermDebtAndCapitalLeaseObligations	us-gaap:LongTermDebtAndCapitalLeaseObligations
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]	us-gaap:OtherLiabilitiesCurrent	us-gaap:OtherLiabilitiesCurrent
Senior Notes and Debentures
Debt Instrument
Weighted average interest rate	4.93%	4.93%
Noble Energy
Debt Instrument
Finance Lease Obligations	$ 193	$ 205
Finance lease obligations, interest rate	0.00%	0.00%
Long-Term Debt Due After One Year	$ 6,402	$ 6,089
Noble Energy | Revolving Credit Facility, due March 9, 2023
Debt Instrument
Debt	$ 325	$ 0
Interest Rate	1.41%	0.00%
Noble Energy | Senior Notes and Debentures
Debt Instrument
Debt	$ 5,884	$ 5,884
Noble Midstream Partners
Debt Instrument
Total debt	1,635	1,495
Noble Midstream Partners | Revolving Credit Facility | Noble Midstream Services Revolving Credit Facility, due March 9, 2023
Debt Instrument
Debt	$ 735	$ 595
Interest Rate	1.61%	3.11%
Noble Midstream Partners | Revolving Credit Facility | Noble Midstream Services Term Loan Credit Facility, due July 31, 2021
Debt Instrument
Debt	$ 500	$ 500
Interest Rate	1.36%	2.85%
Noble Midstream Partners | Revolving Credit Facility | Noble Midstream Services Term Loan Credit Facility, due August 23, 2022
Debt Instrument
Debt	$ 400	$ 400
Interest Rate	1.24%	2.74%

Debt - Narrative (Details)

Debt - Narrative (Details) - USD ($)	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Debt Instrument
Proceeds from revolving credit facilities			$ 1,300,000,000	$ 50,000,000
Repayment of revolving credit facilities			975,000,000	$ 50,000,000
Noble Midstream Services Revolving Credit Facility
Debt Instrument
Available borrowing capacity	$ 415,000,000		415,000,000		$ 555,000,000
Commercial Paper
Debt Instrument
Proceeds from revolving credit facilities		$ 1,000,000,000
Repayment of revolving credit facilities	675,000,000
Revolving credit facility outstanding amount	325,000,000		325,000,000
Noble Midstream | Commercial Paper
Debt Instrument
Available borrowing capacity	3,700,000,000		3,700,000,000		$ 4,000,000,000
Revolving Credit Facility
Debt Instrument
Total borrowing capacity	$ 4,000,000,000		$ 4,000,000,000

Debt - Fair Value of Debt (Deta

Debt - Fair Value of Debt (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Carrying Amount
Debt Instrument
Debt	$ 7,844	$ 7,379
Fair Value
Debt Instrument
Debt	$ 7,529	$ 8,033

Commitments and Contingencies -

Commitments and Contingencies - Narrative (Details) - USD ($) $ in Thousands	1 Months Ended
	Jul. 31, 2020	May 31, 2020	Apr. 30, 2020
Bureau Of Safety And Environmental Enforcement | Subsequent Event
Other Commitments
Amount sought by counterparty	$ 136
Israel’s Ministry Of Environmental Protection
Other Commitments
Amount sought by counterparty		$ 147,000	$ 1,200
Israel’s Ministry Of Environmental Protection | Subsequent Event
Other Commitments
Amount sought by counterparty	$ 632,000
Colorado Oil and Gas Conservation Commission
Other Commitments
Amount sought by counterparty		$ 149

Income Taxes - Components of In

Income Taxes - Components of Income Tax (Benefit) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Current	$ 7	$ 21	$ 44	$ 37
Deferred	(96)	(1)	(144)	(101)
Total Income Tax (Benefit) Expense	$ (89)	$ 20	$ (100)	$ (64)
Effective Tax Rate	18.70%	71.40%	2.20%	18.60%

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020USD ($)
Income Tax Disclosure [Abstract]
Deferred tax expense	$ 470

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Summary of Outstanding Derivative Contracts (Details)	Jun. 30, 2020$ / bblbbl
Crude Oil | NYMEX WTI Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	37,500
Crude Oil | NYMEX WTI Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	14,500
Crude Oil | NYMEX WTI Three-Way Collars 2020
Derivative
Bbls per day (Bbls per day) | bbl	53,000
Crude Oil | NYMEX WTI Sold Calls 2020
Derivative
Bbls per day (Bbls per day) | bbl	8,000
Crude Oil | Midland Basis Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	27,000
Crude Oil | Midland Basis Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	22,000
Crude Oil | WTI Roll Basis Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	78,000
Crude Oil | WTI Roll Basis Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	64,000
Natural Gas Liquids Contract | Ethane Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	6,500
Weighted average fixed price ($ per bbl)	8.39
Natural Gas Liquids Contract | Ethane Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	8,500
Weighted average fixed price ($ per bbl)	8.39
Natural Gas Liquids Contract | Ethane Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	10,500
Weighted average fixed price ($ per bbl)	8.45
Natural Gas Liquids Contract | Ethane Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	8,500
Weighted average fixed price ($ per bbl)	8.60
Natural Gas Liquids Contract | Propane Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	5,000
Weighted average fixed price ($ per bbl)	21.04
Natural Gas Liquids Contract | IsoButane Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	1,000
Weighted average fixed price ($ per bbl)	25.36
Natural Gas Liquids Contract | Butane Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	1,500
Weighted average fixed price ($ per bbl)	24.31
Natural Gas Contract | NYMEX HH - Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	90,000
Natural Gas Contract | NYMEX HH - Sold Puts 2020
Derivative
Bbls per day (Bbls per day) | bbl	90,000
Natural Gas Contract | NYMEX HH Three-Way Collars 2020
Derivative
Bbls per day (Bbls per day) | bbl	40,000
Natural Gas Contract | CIG Basis Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	139,000
Natural Gas Contract | WAHA Basis Swaps 2020
Derivative
Bbls per day (Bbls per day) | bbl	49,500
Natural Gas Contract | NYMEX HH Swaps 2021
Derivative
Bbls per day (Bbls per day) | bbl	70,000
Natural Gas Contract | NYMEX HH Sold Call Swaptions 2021
Derivative
Bbls per day (Bbls per day) | bbl	70,000
Natural Gas Contract | NYMEX HH Three-Way Collars 2021
Derivative
Bbls per day (Bbls per day) | bbl	62,000
Natural Gas Contract | CIG Basis Swaps 2021
Derivative
Bbls per day (Bbls per day) | bbl	114,000
Natural Gas Contract | WAHA Basis Swaps 2021
Derivative
Bbls per day (Bbls per day) | bbl	32,000
Natural Gas Contract | ICE TTF Swaps 2021
Derivative
Bbls per day (Bbls per day) | bbl	35,000
Natural Gas Contract | ICE TTF Swaps 2022
Derivative
Bbls per day (Bbls per day) | bbl	49,000
Swaps | Crude Oil | NYMEX WTI Swaps 2020
Derivative
Weighted average fixed price ($ per bbl)	36.80
Swaps | Crude Oil | NYMEX WTI Swaps 2020
Derivative
Weighted average fixed price ($ per bbl)	51.91
Swaps | Crude Oil | NYMEX WTI Sold Calls 2020
Derivative
Weighted average fixed price ($ per bbl)	65.59
Swaps | Crude Oil | Midland Basis Swaps 2020
Derivative
Weighted average differential ($ per bbl)	(4.03)
Swaps | Crude Oil | Midland Basis Swaps 2020
Derivative
Weighted average differential ($ per bbl)	(4.21)
Swaps | Crude Oil | WTI Roll Basis Swaps 2020
Derivative
Weighted average differential ($ per bbl)	(2.28)
Swaps | Crude Oil | WTI Roll Basis Swaps 2020
Derivative
Weighted average differential ($ per bbl)	(2.19)
Swaps | Natural Gas Contract | NYMEX HH - Swaps 2020
Derivative
Weighted average fixed price ($ per bbl)	2.60
Swaps | Natural Gas Contract | CIG Basis Swaps 2020
Derivative
Weighted average differential ($ per bbl)	(0.57)
Swaps | Natural Gas Contract | WAHA Basis Swaps 2020
Derivative
Weighted average differential ($ per bbl)	(1.05)
Swaps | Natural Gas Contract | NYMEX HH Swaps 2021
Derivative
Weighted average fixed price ($ per bbl)	2.42
Swaps | Natural Gas Contract | NYMEX HH Sold Call Swaptions 2021
Derivative
Weighted average fixed price ($ per bbl)	2.42
Swaps | Natural Gas Contract | CIG Basis Swaps 2021
Derivative
Weighted average differential ($ per bbl)	(0.44)
Swaps | Natural Gas Contract | WAHA Basis Swaps 2021
Derivative
Weighted average differential ($ per bbl)	(0.71)
Swaps | Natural Gas Contract | ICE TTF Swaps 2021
Derivative
Weighted average fixed price ($ per bbl)	4.15
Swaps | Natural Gas Contract | ICE TTF Swaps 2022
Derivative
Weighted average fixed price ($ per bbl)	4.26
Collars | Crude Oil | NYMEX WTI Three-Way Collars 2020
Derivative
Weighted average short put price ($ per bbl)	10
Weighted average floor price ($ per bbl)	25
Weighted average ceiling price ($ per bbl)	37.20
Collars | Natural Gas Contract | NYMEX HH - Sold Puts 2020
Derivative
Weighted average short put price ($ per bbl)	2.15
Collars | Natural Gas Contract | NYMEX HH Three-Way Collars 2020
Derivative
Weighted average short put price ($ per bbl)	2.25
Weighted average floor price ($ per bbl)	2.70
Weighted average ceiling price ($ per bbl)	2.85
Collars | Natural Gas Contract | NYMEX HH Three-Way Collars 2021
Derivative
Weighted average short put price ($ per bbl)	1.90
Weighted average floor price ($ per bbl)	2.40
Weighted average ceiling price ($ per bbl)	2.88

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Fair Value Amounts and (Gain) Loss on Commodity Derivative Instruments (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Derivatives, Fair Value
Asset Derivative Instruments	$ 61			$ 61		$ 15
Liability Derivative Instruments	166			166		37
Total Cash Received in Settlement of Commodity Derivative Instruments	(106)		$ (1)	(314)	$ (15)
Total Non-cash Portion of Loss (Gain) on Commodity Derivative Instruments	264		(59)	83	167
Total Loss (Gain) on Commodity Derivative Instruments	158		(60)	(231)	152
Proceeds from derivative settlement		$ 160
Other Current Assets
Derivatives, Fair Value
Asset Derivative Instruments	61			61		14
Other Current Liabilities
Derivatives, Fair Value
Liability Derivative Instruments	151			151		36
Other Noncurrent Assets
Derivatives, Fair Value
Asset Derivative Instruments	0			0		1
Other Noncurrent Liabilities
Derivatives, Fair Value
Liability Derivative Instruments	15			15		$ 1
Crude Oil
Derivatives, Fair Value
Total Cash Received in Settlement of Commodity Derivative Instruments	(103)		7	(313)	(2)
Total Non-cash Portion of Loss (Gain) on Commodity Derivative Instruments	226		(54)	39	169
Total Loss (Gain) on Commodity Derivative Instruments	123		(47)	(274)	167
NGL
Derivatives, Fair Value
Total Cash Received in Settlement of Commodity Derivative Instruments	(3)		0	(3)	0
Total Non-cash Portion of Loss (Gain) on Commodity Derivative Instruments	10		0	0	0
Total Loss (Gain) on Commodity Derivative Instruments	7		0	(3)	0
Natural Gas
Derivatives, Fair Value
Total Cash Received in Settlement of Commodity Derivative Instruments	0		(8)	2	(13)
Total Non-cash Portion of Loss (Gain) on Commodity Derivative Instruments	28		(5)	44	(2)
Total Loss (Gain) on Commodity Derivative Instruments	$ 28		$ (13)	$ 46	$ (15)

Net Loss Per Share Attributab_3

Net Loss Per Share Attributable to Noble Energy Common Shareholders (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Earnings Per Share [Abstract]
Net Loss and Comprehensive Loss Attributable to Noble Energy	$ (408)	$ (10)	$ (4,371)	$ (323)
Weighted average number of shares outstanding, basic (in shares)	479	478	480	478
Incremental shares from assumed conversion of dilutive stock options, restricted stock, and shares of common stock in rabbi trust (in shares)	0	0	0	0
Weighted average number of shares outstanding, diluted (in shares)	479	478	480	478
Loss per share, basic and diluted ($ per share)	$ (0.85)	$ (0.02)	$ (9.11)	$ (0.68)
Number of Antidilutive Stock Options, Shares of Restricted Stock, and Shares of Common Stock in Rabbi Trust Excluded from Calculation Above	16	15	16	15