Noble Energy (NBL) 10-Q 8 May 20 2020 Q1 Quarterly report Financial data

Cover Page

Cover Page	3 Months Ended
	Mar. 31, 2020shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 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 12(b) Security	Common Stock, $0.01 par value
Trading Symbol	NBL
Security Exchange Name	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	479,698,676
Entity Central Index Key	0000072207
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1
Amendment Flag	false

Consolidated Statements of Oper

Consolidated Statements of Operations and Comprehensive Loss - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Revenues
Revenue from Sales	$ 1,020	$ 1,052
Total	1,020	1,052
Costs and Expenses
Production Expense	276	305
Exploration Expense	1,504	24
Depreciation, Depletion and Amortization	492	508
General and Administrative	85	102
Asset Impairments	2,703	0
Goodwill impairment	110	0
Other Operating Expense, Net	44	117
Total	5,353	1,143
Operating Expense	(4,333)	(91)
Other (Income) Expense
(Gain) Loss on Commodity Derivative Instruments	(389)	212
Interest, Net of Amount Capitalized	81	66
Other Non-Operating (Income) Expense , Net	(7)	4
Total	(315)	282
Loss Before Income Taxes	(4,018)	(373)
Income Tax Benefit	(11)	(84)
Net Loss and Comprehensive Loss Including Noncontrolling Interests	(4,007)	(289)
Less: Net (Loss) Income and Comprehensive (Loss) Income Attributable to Noncontrolling Interests	(44)	24
Net Loss and Comprehensive Loss Attributable to Noble Energy	$ (3,963)	$ (313)
Net Loss Attributable to Noble Energy Common Shareholders per Share
Basic and Diluted ($ per share)	$ (8.27)	$ (0.65)
Weighted Average Number of Common Shares Outstanding
Basic and Diluted (in shares)	479	478
Oil, NGL and Gas Sales
Revenues
Revenue from Sales	$ 894	$ 937
Sales of Purchased Oil and Gas
Revenues
Revenue from Sales	125	74
Costs and Expenses
Cost of Purchased Oil and Gas	139	87
Other Revenue
Revenues
Revenue from Sales	$ 1	$ 41

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Current Assets
Cash and Cash Equivalents	$ 1,397	$ 484
Accounts Receivable, Net	562	730
Other Current Assets	353	148
Total Current Assets	2,312	1,362
Property, Plant and Equipment
Oil and Gas Properties (Successful Efforts Method of Accounting)	30,824	30,404
Property, Plant and Equipment, Other	1,087	1,083
Total Property, Plant and Equipment, Gross	31,911	31,487
Accumulated Depreciation, Depletion and Amortization	(18,690)	(14,036)
Total Property, Plant and Equipment, Net	13,221	17,451
Other Noncurrent Assets	1,925	1,834
Total Assets	17,458	20,647
Current Liabilities
Accounts Payable – Trade	1,099	1,250
Other Current Liabilities	651	719
Total Current Liabilities	1,750	1,969
Long-Term Debt	8,632	7,477
Deferred Income Taxes	615	662
Other Noncurrent Liabilities	1,306	1,378
Total Liabilities	12,303	11,486
Commitments and Contingencies
Mezzanine Equity
Redeemable Noncontrolling Interest, Net	109	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	8,942	8,927
Accumulated Other Comprehensive Loss	(30)	(31)
Treasury Stock, at Cost; 39 Million Shares	(740)	(732)
(Accumulated Deficit) Retained Earnings	(3,780)	241
Noble Energy Share of Equity	4,397	8,410
Noncontrolling Interests	649	645
Total Shareholders' Equity	5,046	9,055
Total Liabilities, Mezzanine Equity and Shareholders' Equity	$ 17,458	$ 20,647

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Mar. 31, 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	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Cash Flows From Operating Activities
Net Loss Including Noncontrolling Interests	$ (4,007)	$ (289)
Adjustments to Reconcile Net Loss to Net Cash Provided by Operating Activities
Leasehold Impairment	1,485	0
Depreciation, Depletion and Amortization	492	508
Deferred Income Tax Benefit	(48)	(100)
(Gain) Loss on Commodity Derivative Instruments	(389)	212
Net Cash Received in Settlement of Commodity Derivative Instruments	208	14
Asset Impairments	2,703	0
Goodwill Impairment	110	0
Firm Transportation Exit Cost	0	92
Other Adjustments for Noncash Items Included in Income	82	28
Changes in Operating Assets and Liabilities
Decrease in Accounts Receivable	90	9
(Decrease) Increase in Accounts Payable	(48)	106
Other Current Assets and Liabilities, Net	(122)	(7)
Other Operating Assets and Liabilities, Net	(74)	(45)
Net Cash Provided by Operating Activities	482	528
Cash Flows From Investing Activities
Additions to Property, Plant and Equipment	(479)	(763)
Additions to Equity Method Investments	(226)	(271)
Proceeds from Divestitures, Net	17	123
Other	(8)	0
Net Cash Used in Investing Activities	(696)	(911)
Cash Flows From Financing Activities
Dividends Paid, Common Stock	(58)	(53)
Contributions from Noncontrolling Interest Owners	78	10
Proceeds from Issuance of Mezzanine Equity, Net of Offering Costs	0	99
Other	(48)	(32)
Net Cash Provided by Financing Activities	1,127	194
Increase (Decrease) in Cash, Cash Equivalents, and Restricted Cash	913	(189)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	484	719
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,397	530
Revolving Credit Facility
Cash Flows From Financing Activities
Proceeds from Revolving Credit Facilities	1,120	50
Repayment of Revolving Credit Facilities	(120)	(50)
Noble Midstream Services Revolving Credit Facility | Revolving Credit Facility
Cash Flows From Financing Activities
Proceeds from Revolving Credit Facilities	260	345
Repayment of Revolving Credit Facilities	$ (105)	$ (175)

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 [Roll Forward]
Net Loss	(289)					(313)	24
Stock-based Compensation	14		14
Dividends	(53)					(53)
Distributions to Noncontrolling Interest Owners	(17)		0	0			(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, 2019	9,055	5	8,927	(31)	(732)	241	645
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Loss	(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

Consolidated Statements of Sh_2

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

Organization and Nature of Oper

Organization and Nature of Operations	3 Months Ended
	Mar. 31, 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.

Basis of Presentation

Basis of Presentation	3 Months Ended
	Mar. 31, 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 March 31, 2020 and December 31, 2019 and for the three months ended March 31, 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 months ended March 31, 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 three months ended March 31, 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 contributed significant uncertainty to our estimates this quarter. Actual results could differ significantly from those estimates. Impairments During the quarter, we identified certain impairment indicators including the recent significant decrease in commodity prices as a result of the COVID-19 pandemic lowering demand for our products, as well as the supply response from the Organization of Petroleum Exporting Countries (OPEC) and non-OPEC producers, factors which have caused us to change our development plans . Due to these impairment indicators, we conducted impairment testing of certain of our assets, 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 include expectations for future commodity prices, development and capital spending plans, reservoir performance and production . Additionally, these estimates include 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 is 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 the quarter, 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 the quarter, 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, 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). The current commodity price environment and decrease in market capitalization were indicators that the 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. Noble Midstream Partners then performed a fair value assessment, taking into account changes in customer development plans. Based on these assessments, Noble Midstream Partners concluded that the goodwill was fully impaired. 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, we recorded an impairment to our Delaware Basin proved and unproved properties and to our Eagle Ford Shale unproved properties. Together, these factors suggest that it is more likely than not that our forecasted domestic net deferred tax asset will not be realized. 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 Israel, certain of our Tamar and Leviathan natural gas sales and purchase agreements (GSPAs) have fixed minimum sales volumes and fixed base pricing with annual index escalations. Additionally, certain of our Egyptian export contracts include provisions which trigger adjustments to either decrease, or increase, fixed minimum sales volumes in the event the arithmetic average of daily Brent crude oil prices fall below, or above, $50 per barrel for certain periods of time. Estimated future revenues related to remaining performance obligations were as follows as of March 31, 2020: (millions) Remainder of 2020 2021 2022 2023 2024 Thereafter Total Natural Gas Revenues (1) $ 407 $ 599 $ 418 $ 412 $ 412 $ 3,695 $ 5,943 (1) 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. 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 March 31, (millions) 2020 2019 Other Revenue (Loss) Income from Equity Method Investments and Other $ (24 ) $ 17 Midstream Services Revenues – Third Party 25 24 Total $ 1 $ 41 Production Expense Lease Operating Expense $ 138 $ 151 Production and Ad Valorem Taxes 39 49 Gathering, Transportation and Processing Expense 95 102 Other Royalty Expense 4 3 Total $ 276 $ 305 Exploration Expense Leasehold Impairment (1) $ 1,485 $ — Seismic, Geological and Geophysical 4 5 Staff Expense 13 12 Other 2 7 Total $ 1,504 $ 24 Other Operating Expense, Net Finance Lease Right-of-Use Asset Impairment (2) $ 40 $ — Firm Transportation Exit Cost — 92 Other, Net 4 25 Total $ 44 $ 117 (1) See Note 4. Impairments and Note 6. Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs . (2) See Note 4. Impairments . Balance Sheet Information Other balance sheet information is as follows: (millions) March 31, December 31, Accounts Receivable, Net Commodity Sales $ 308 $ 446 Joint Interest Billings 136 164 Other 125 128 Current Expected Credit Losses (7 ) (8 ) Total $ 562 $ 730 Other Current Assets Commodity Derivative Assets $ 221 $ 14 Inventories, Materials and Supplies 68 59 Assets Held for Sale (1) 1 14 Prepaid Expenses and Other Current Assets 63 61 Total $ 353 $ 148 Other Noncurrent Assets Equity Method Investments $ 1,249 $ 1,066 Operating Lease Right-of-Use Assets, Net (2) 244 227 Customer-Related Intangible Assets, Net (3) 270 278 Goodwill (4) — 110 Other Assets, Noncurrent 162 153 Total $ 1,925 $ 1,834 Other Current Liabilities Production and Ad Valorem Taxes $ 113 $ 118 Asset Retirement Obligations 84 84 Interest Payable 80 74 Operating Lease Liabilities 95 88 Compensation and Benefits Payable 25 126 Other Liabilities, Current 254 229 Total $ 651 $ 719 Other Noncurrent Liabilities Deferred Compensation Liabilities $ 112 $ 133 Asset Retirement Obligations 709 730 Operating Lease Liabilities 172 164 Firm Transportation Exit Cost Accrual (5) 114 129 Other Liabilities, Noncurrent 199 222 Total $ 1,306 $ 1,378 (1) Assets held for sale at December 31, 2019 relate to the divestiture of non-core assets in Reeves County, Texas. The assets were reclassified to held and used during first quarter 2020. (2) Amount at March 31, 2020 includes a five -year $28 million lease renewal for a vessel offshore West Africa. (3) Intangible asset balances at March 31, 2020 and December 31, 2019 are net of accumulated amortization of $70 million and $62 million , respectively. (4) See Note 4. Impairments . (5) 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: Three Months Ended March 31, (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 $ 1,397 $ 528 Restricted Cash at End of Period — 2 Cash, Cash Equivalents, and Restricted Cash at End of Period $ 1,397 $ 530

Segment Information

Segment Information	3 Months Ended
	Mar. 31, 2020
Segment Reporting [Abstract]
Segment Information	Note 3. Segment Information We have the following reportable segments: US onshore; Eastern Mediterranean (Israel and Cyprus); West Africa (Equatorial Guinea, Cameroon and Gabon); Other International (Canada, Colombia and New Ventures); and Midstream. The Midstream segment includes the consolidated accounts of Noble Midstream Partners. The geographical reportable segments 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 and certain costs associated with mitigating the effects of our retained Marcellus Shale transportation agreements, are recorded at the Corporate level. 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 March 31, 2020 Crude Oil Sales $ 578 $ 492 $ 1 $ 85 $ — $ — $ — $ — NGL Sales 62 62 — — — — — — Natural Gas Sales 254 60 190 4 — — — — Total Crude Oil, NGL and Natural Gas Sales 894 614 191 89 — — — — Sales of Purchased Oil and Gas 125 25 — — — 83 — 17 Loss from Equity Method Investments and Other (24 ) — (2 ) (17 ) — (5 ) — — Midstream Services Revenues – Third Party 25 — — — — 25 — — Intersegment Revenues — — — — — 115 (115 ) — Total Revenues 1,020 639 189 72 — 218 (115 ) 17 Lease Operating Expense 138 108 13 30 — 1 (14 ) — Production and Ad Valorem Taxes 39 37 — — — 2 — — Gathering, Transportation and Processing Expense 95 146 3 — — 21 (75 ) — Other Royalty Expense 4 4 — — — — — — Total Production Expense 276 295 16 30 — 24 (89 ) — Exploration Expense 1,504 1,494 2 3 5 — — — 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 492 419 19 24 — 26 (9 ) 13 Cost of Purchased Oil and Gas 139 28 — — — 80 — 31 Asset Impairments 2,703 2,703 — — — — — — Goodwill Impairment 110 — — — — 110 — — Gain on Commodity Derivative Instruments (389 ) (389 ) — — — — — — (Loss) Income Before Income Taxes (4,018 ) (3,917 ) 145 10 (6 ) (31 ) (11 ) (208 ) Additions to Long-Lived Assets, Excluding Acquisitions 442 357 31 19 9 43 (24 ) 7 Additions to Equity Method Investments 153 — — — — 153 — — Three Months Ended March 31, 2019 Crude Oil Sales $ 612 $ 545 $ 1 $ 66 $ — $ — $ — $ — NGL Sales 96 96 — — — — — — Natural Gas Sales 229 108 117 4 — — — — Total Crude Oil, NGL and Natural Gas Sales 937 749 118 70 — — — — Sales of Purchased Oil and Gas 74 14 — — — 33 — 27 Income from Equity Method Investments and Other 17 — — 15 — 2 — — Midstream Services Revenues – Third Party 24 — — — — 24 — — Intersegment Revenues — — — — — 106 (106 ) — Total Revenues 1,052 763 118 85 — 165 (106 ) 27 Lease Operating Expense 151 125 10 24 — 1 (9 ) — Production and Ad Valorem Taxes 49 47 — — — 2 — — Gathering, Transportation and Processing Expense 102 142 — — — 29 (69 ) — Other Royalty Expense 3 3 — — — — — — Total Production Expense 305 317 10 24 — 32 (78 ) — Depreciation, Depletion and Amortization 508 439 16 20 — 25 (7 ) 15 Cost of Purchased Oil and Gas 87 14 — — — 31 — 42 Firm Transportation Exit Cost 92 — — — — — — 92 Loss on Commodity Derivative Instruments 212 188 — 24 — — — — (Loss) Income Before Income Taxes (373 ) (247 ) 84 11 (16 ) 73 (14 ) (264 ) Additions to Long-Lived Assets, Excluding Acquisitions 712 511 132 5 10 66 (23 ) 11 Additions to Equity Method Investments 271 — — — — 271 — — March 31, 2020 Property, Plant and Equipment, Net $ 13,221 $ 7,641 $ 3,055 $ 792 $ 53 $ 1,734 $ (225 ) $ 171 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 December 31, 2019 Property, Plant and Equipment, Net $ 17,451 $ 11,859 $ 3,041 $ 793 $ 44 $ 1,721 $ (223 ) $ 216 (1)

Impairments (Notes)

Impairments (Notes)	3 Months Ended
	Mar. 31, 2020
Other Income and Expenses [Abstract]
Impairments	Note 4. 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 . Information regarding impairments recorded in first quarter 2020 is as follows: (millions) Statement of Operations Location Net Book Value (1) Pre-tax Impairment Proved Property Impairment - Delaware Basin Asset Impairments $ 3,613 $ 2,703 Leasehold Impairment - Delaware Basin Exploration Expense 1,915 1,385 Leasehold Impairment - Eagle Ford Shale Exploration Expense 100 100 Total Exploration Expense $ 2,015 $ 1,485 Goodwill Impairment - Noble Midstream Partners Goodwill Impairment $ 110 $ 110 Finance Lease Right-of-Use Asset Impairment Other Operating Expense, Net 88 40 (1) Represents net book value at the date of assessment prior to recording pre-tax impairment. 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. 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 . 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

Acquisitions, Divestitures and

Acquisitions, Divestitures and Equity Method Investments	3 Months Ended
	Mar. 31, 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. In first quarter 2020, Noble Midstream Partners made capital contributions to EPIC Y-Grade and EPIC Crude Holdings of $14 million and $33 million, respectively. EPIC Crude Holdings completed the EPIC crude oil pipeline during first quarter 2020 and the EPIC Y-grade pipeline is transitioning from interim crude service to Y-grade service. Y-grade service is expected to begin in second quarter 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. In first quarter 2020, Noble Midstream Partners made capital contributions to EPIC Propane of approximately $2 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. In first quarter 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. Delaware Crossing Joint Venture In first quarter 2019 Noble Midstream Partners made capital contributions of $ 38

Capitalized Exploratory Well Co

Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs	3 Months Ended
	Mar. 31, 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 There were no significant changes to our capitalized exploratory well costs during the period. The following table provides an aging of capitalized exploratory well costs based on the date that drilling commenced: (millions, except number of projects) March 31, 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 261 258 Capitalized Exploratory Well Costs, End of Period $ 291 $ 280 Number of Projects with Exploratory Well Costs That Have Been Capitalized for a Period Greater Than One Year Since Commencement of Drilling 5 5 Undeveloped Leasehold Costs Changes in undeveloped leasehold costs are as follows: (millions) Three Months Ended March 31, 2020 Undeveloped Leasehold Costs, Beginning of Period $ 2,152 Additions to Undeveloped Leasehold Costs 2 Impairment (1) (1,485 ) Other (2 ) Undeveloped Leasehold Costs, End of Period $ 667 (1) Relates to impairments of undeveloped leasehold costs for unproved properties in the Delaware Basin and Eagle Ford Shale. See Note 2. Basis of Presentation and Note 4. Impairments . As of March 31, 2020 , undeveloped leasehold costs included $530 million, $80 million, and $57 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	3 Months Ended
	Mar. 31, 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: Three Months Ended March 31, (millions) 2020 2019 Asset Retirement Obligations, Beginning Balance $ 814 $ 880 Liabilities Incurred 3 2 Liabilities Settled (27 ) (27 ) Revisions of Estimates (8 ) — Accretion Expense 11 12 Asset Retirement Obligations, Ending Balance $ 793 $ 867 Three Months Ended March 31, 2020 Liabilities settled primarily relate to abandonment of US onshore properties, with $ 21 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 the timing of spend in the DJ Basin. Three Months Ended March 31, 2019 Liabilities settled of $27 million

Debt

Debt	3 Months Ended
	Mar. 31, 2020
Debt Disclosure [Abstract]
Debt	Note 8. Debt Debt consists of the following: March 31, 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 $ 1,000 1.92 % $ — — % Senior Notes and Debentures 5,884 (1 ) 5,884 (1 ) Finance Lease Obligations 203 — % 205 — % Total Noble Energy Debt, Excluding Noble Midstream Partners Debt 7,087 6,089 Noble Midstream Partners Noble Midstream Services Revolving Credit Facility, due March 9, 2023 750 2.16 % 595 3.11 % Noble Midstream Services Term Loan Credit Facility, due July 31, 2021 500 1.94 % 500 2.85 % Noble Midstream Services Term Loan Credit Facility, due August 23, 2022 400 1.82 % 400 2.74 % Total Noble Midstream Partners Debt 1,650 1,495 Total Debt 8,737 7,584 Net Unamortized Discounts and Debt Issuance Costs (64 ) (65 ) Total Debt, Net of Unamortized Discounts and Debt Issuance Costs 8,673 7,519 Less Amounts Due Within One Year Finance Lease Obligations (41 ) (42 ) Long-Term Debt Due After One Year $ 8,632 $ 7,477 (1) The Senior Notes and Debentures have weighted average interest rates of 4.93% for both March 31, 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 the quarter, 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 . As of March 31, 2020 and December 31, 2019 , the Revolving Credit Facility had $ 3.0 billion and $ 4.0 billion available for borrowing, respectively. Noble Midstream Partners borrowed $ 155 million, net, on the Noble Midstream Services Revolving Credit Facility. Proceeds received were used to partially fund the investment in Saddlehorn, capital investment program and for working capital purposes. As of March 31, 2020 and December 31, 2019 , the Noble Midstream Services Revolving Credit Facility had $ 400 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: March 31, 2020 December 31, 2019 (millions) Carrying Amount Fair Value (1) Carrying Amount Fair Value Debt $ 8,534 $ 6,705 $ 7,379 $ 8,033 (1) As of March 31, 2020 , the difference between the carrying amount and the fair value is primarily due to increased spreads resulting from the current commodity price, supply and demand environment coupled with the COVID-19 pandemic .

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 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. 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	3 Months Ended
	Mar. 31, 2020
Income Tax Disclosure [Abstract]
Income Taxes	Note 10. Income Taxes Income tax expense (benefit) consists of the following: Three Months Ended March 31, (millions, except percentages) 2020 2019 Current $ 37 $ 16 Deferred (48 ) (100 ) Total Income Tax Benefit $ (11 ) $ (84 ) Effective Tax Rate 0.27 % 22.5 % 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. Due to the impairments recorded during first quarter 2020, we have 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 three months ended March 31, 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. In addition, the increase in current tax expense was the result of increased earnings in our Eastern Mediterranean segment. 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 March 31, 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	3 Months Ended
	Mar. 31, 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 March 31, 2020 , we had entered into the following crude oil derivative instruments: Swaps Collars Settlement Period 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 Apr2020-Dec2020 Sold Calls NYMEX WTI 8,000 $ — $ 65.59 $ — $ — $ — Apr2020-Dec2020 Swaps NYMEX WTI 11,500 — 57.79 — — — Apr2020-Jun2020 Swaps NYMEX WTI 72,000 — 37.09 — — — Jul2020-Dec2020 Three-Way Collars NYMEX WTI 53,000 — — 10.00 25.00 37.20 Jul2020-Dec2020 Call Swaption NYMEX WTI 11,000 — 58.95 — — — 2020 Basis Swaps Midland (1) 15,000 (5.01 ) — — — — (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. As of March 31, 2020 , we had entered into the following natural gas liquid (NGL) derivative instruments: Swaps Settlement Period Type of Contract Index Bbls per Day Weighted Average Fixed Price Apr 2020-Sept 2020 Ethane Swaps Mont Belvieu 2,000 $ 7.77 Apr 2020-Sept 2020 Propane Swaps Mont Belvieu 5,000 21.04 Apr 2020-Sept 2020 Isobutane Swaps Mont Belvieu 1,000 25.36 Apr 2020-Sept 2020 Butane Swaps Mont Belvieu 1,500 24.31 As of March 31, 2020 , we had entered into the following natural gas derivative instruments: Swaps Collars Settlement Period 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 Apr2020-Dec2020 Swaps NYMEX HH 90,000 $ — $ 2.60 $ — $ — $ — Apr2020-Oct2020 Three-Way Collars NYMEX HH 40,000 — — 2.25 2.70 2.85 Apr2020-Dec2020 Sold Puts NYMEX HH 90,000 — — 2.15 — — 2020 Basis Swaps CIG (1) 139,000 (0.56 ) — — — — 2020 Basis Swaps WAHA (1) 49,500 (1.05 ) — — — — 2021 Swaps NYMEX HH 70,000 — 2.42 — — — 2021 Call Swaption NYMEX HH 70,000 — 2.42 — — — 2021 Basis Swaps CIG (1) 60,000 (0.52 ) — — — — 2021 Basis Swaps WAHA (1) 32,000 (0.71 ) — — — — (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. 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 March 31, 2020 December 31, 2019 Balance Sheet Location March 31, 2020 December 31, 2019 Other Current Assets $ 221 $ 14 Other Current Liabilities $ 59 $ 36 Other Noncurrent Assets — 1 Other Noncurrent Liabilities 3 1 Total $ 221 $ 15 $ 62 $ 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 March 31, (millions) 2020 2019 Cash (Received) Paid in Settlement of Commodity Derivative Instruments Crude Oil (1) $ (210 ) $ (9 ) NGL — — Natural Gas 2 (5 ) Total Cash Received in Settlement of Commodity Derivative Instruments (208 ) (14 ) Non-cash Portion of (Gain) Loss on Commodity Derivative Instruments Crude Oil (187 ) 223 NGL (10 ) — Natural Gas 16 3 Total Non-cash Portion of (Gain) Loss on Commodity Derivative Instruments (181 ) 226 (Gain) Loss on Commodity Derivative Instruments Crude Oil (397 ) 214 NGL (10 ) — Natural Gas 18 (2 ) Total (Gain) Loss on Commodity Derivative Instruments $ (389 ) $ 212 (1) During first quarter 2020, we monetized certain crude oil derivative instruments by settling the instruments prior to their original settlement dates and 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	3 Months Ended
	Mar. 31, 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 March 31, (millions, except per share amounts) 2020 2019 Net Loss and Comprehensive Loss Attributable to Noble Energy $ (3,963 ) $ (313 ) Weighted Average Number of Shares Outstanding, Basic 479 478 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 Loss Per Share, Basic and Diluted $ (8.27 ) $ (0.65 ) Number of Antidilutive Stock Options, Shares of Restricted Stock, and Shares of Common Stock in Rabbi Trust Excluded from Calculation Above 16 15

Basis of Presentation (Policies

Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 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 March 31, 2020 and December 31, 2019 and for the three months ended March 31, 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 months ended March 31, 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.
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 contributed significant uncertainty to our estimates this quarter. 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 Israel, certain of our Tamar and Leviathan natural gas sales and purchase agreements (GSPAs) have fixed minimum sales volumes and fixed base pricing with annual index escalations. Additionally, certain of our Egyptian export contracts include provisions which trigger adjustments to either decrease, or increase, fixed minimum sales volumes in the event the arithmetic average of daily Brent crude oil prices fall below, or above, $50 per barrel for certain periods of time.
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 three months ended March 31, 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.
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)	3 Months Ended
	Mar. 31, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	Estimated future revenues related to remaining performance obligations were as follows as of March 31, 2020: (millions) Remainder of 2020 2021 2022 2023 2024 Thereafter Total Natural Gas Revenues (1) $ 407 $ 599 $ 418 $ 412 $ 412 $ 3,695 $ 5,943 (1) 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. Actual results could differ significantly from these estimates.
Statement of Operations Information	Other statements of operations information is as follows: Three Months Ended March 31, (millions) 2020 2019 Other Revenue (Loss) Income from Equity Method Investments and Other $ (24 ) $ 17 Midstream Services Revenues – Third Party 25 24 Total $ 1 $ 41 Production Expense Lease Operating Expense $ 138 $ 151 Production and Ad Valorem Taxes 39 49 Gathering, Transportation and Processing Expense 95 102 Other Royalty Expense 4 3 Total $ 276 $ 305 Exploration Expense Leasehold Impairment (1) $ 1,485 $ — Seismic, Geological and Geophysical 4 5 Staff Expense 13 12 Other 2 7 Total $ 1,504 $ 24 Other Operating Expense, Net Finance Lease Right-of-Use Asset Impairment (2) $ 40 $ — Firm Transportation Exit Cost — 92 Other, Net 4 25 Total $ 44 $ 117 (1) See Note 4. Impairments and Note 6. Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs . (2) See Note 4. Impairments .
Balance Sheet Information Table	Other balance sheet information is as follows: (millions) March 31, December 31, Accounts Receivable, Net Commodity Sales $ 308 $ 446 Joint Interest Billings 136 164 Other 125 128 Current Expected Credit Losses (7 ) (8 ) Total $ 562 $ 730 Other Current Assets Commodity Derivative Assets $ 221 $ 14 Inventories, Materials and Supplies 68 59 Assets Held for Sale (1) 1 14 Prepaid Expenses and Other Current Assets 63 61 Total $ 353 $ 148 Other Noncurrent Assets Equity Method Investments $ 1,249 $ 1,066 Operating Lease Right-of-Use Assets, Net (2) 244 227 Customer-Related Intangible Assets, Net (3) 270 278 Goodwill (4) — 110 Other Assets, Noncurrent 162 153 Total $ 1,925 $ 1,834 Other Current Liabilities Production and Ad Valorem Taxes $ 113 $ 118 Asset Retirement Obligations 84 84 Interest Payable 80 74 Operating Lease Liabilities 95 88 Compensation and Benefits Payable 25 126 Other Liabilities, Current 254 229 Total $ 651 $ 719 Other Noncurrent Liabilities Deferred Compensation Liabilities $ 112 $ 133 Asset Retirement Obligations 709 730 Operating Lease Liabilities 172 164 Firm Transportation Exit Cost Accrual (5) 114 129 Other Liabilities, Noncurrent 199 222 Total $ 1,306 $ 1,378 (1) Assets held for sale at December 31, 2019 relate to the divestiture of non-core assets in Reeves County, Texas. The assets were reclassified to held and used during first quarter 2020. (2) Amount at March 31, 2020 includes a five -year $28 million lease renewal for a vessel offshore West Africa. (3) Intangible asset balances at March 31, 2020 and December 31, 2019 are net of accumulated amortization of $70 million and $62 million , respectively. (4) See Note 4. Impairments . (5) 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: Three Months Ended March 31, (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 $ 1,397 $ 528 Restricted Cash at End of Period — 2 Cash, Cash Equivalents, and Restricted Cash at End of Period $ 1,397 $ 530

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2020
Segment Reporting [Abstract]
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 March 31, 2020 Crude Oil Sales $ 578 $ 492 $ 1 $ 85 $ — $ — $ — $ — NGL Sales 62 62 — — — — — — Natural Gas Sales 254 60 190 4 — — — — Total Crude Oil, NGL and Natural Gas Sales 894 614 191 89 — — — — Sales of Purchased Oil and Gas 125 25 — — — 83 — 17 Loss from Equity Method Investments and Other (24 ) — (2 ) (17 ) — (5 ) — — Midstream Services Revenues – Third Party 25 — — — — 25 — — Intersegment Revenues — — — — — 115 (115 ) — Total Revenues 1,020 639 189 72 — 218 (115 ) 17 Lease Operating Expense 138 108 13 30 — 1 (14 ) — Production and Ad Valorem Taxes 39 37 — — — 2 — — Gathering, Transportation and Processing Expense 95 146 3 — — 21 (75 ) — Other Royalty Expense 4 4 — — — — — — Total Production Expense 276 295 16 30 — 24 (89 ) — Exploration Expense 1,504 1,494 2 3 5 — — — 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 492 419 19 24 — 26 (9 ) 13 Cost of Purchased Oil and Gas 139 28 — — — 80 — 31 Asset Impairments 2,703 2,703 — — — — — — Goodwill Impairment 110 — — — — 110 — — Gain on Commodity Derivative Instruments (389 ) (389 ) — — — — — — (Loss) Income Before Income Taxes (4,018 ) (3,917 ) 145 10 (6 ) (31 ) (11 ) (208 ) Additions to Long-Lived Assets, Excluding Acquisitions 442 357 31 19 9 43 (24 ) 7 Additions to Equity Method Investments 153 — — — — 153 — — Three Months Ended March 31, 2019 Crude Oil Sales $ 612 $ 545 $ 1 $ 66 $ — $ — $ — $ — NGL Sales 96 96 — — — — — — Natural Gas Sales 229 108 117 4 — — — — Total Crude Oil, NGL and Natural Gas Sales 937 749 118 70 — — — — Sales of Purchased Oil and Gas 74 14 — — — 33 — 27 Income from Equity Method Investments and Other 17 — — 15 — 2 — — Midstream Services Revenues – Third Party 24 — — — — 24 — — Intersegment Revenues — — — — — 106 (106 ) — Total Revenues 1,052 763 118 85 — 165 (106 ) 27 Lease Operating Expense 151 125 10 24 — 1 (9 ) — Production and Ad Valorem Taxes 49 47 — — — 2 — — Gathering, Transportation and Processing Expense 102 142 — — — 29 (69 ) — Other Royalty Expense 3 3 — — — — — — Total Production Expense 305 317 10 24 — 32 (78 ) — Depreciation, Depletion and Amortization 508 439 16 20 — 25 (7 ) 15 Cost of Purchased Oil and Gas 87 14 — — — 31 — 42 Firm Transportation Exit Cost 92 — — — — — — 92 Loss on Commodity Derivative Instruments 212 188 — 24 — — — — (Loss) Income Before Income Taxes (373 ) (247 ) 84 11 (16 ) 73 (14 ) (264 ) Additions to Long-Lived Assets, Excluding Acquisitions 712 511 132 5 10 66 (23 ) 11 Additions to Equity Method Investments 271 — — — — 271 — — March 31, 2020 Property, Plant and Equipment, Net $ 13,221 $ 7,641 $ 3,055 $ 792 $ 53 $ 1,734 $ (225 ) $ 171 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 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 income (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)	3 Months Ended
	Mar. 31, 2020
Other Income and Expenses [Abstract]
Impairment	Information regarding impairments recorded in first quarter 2020 is as follows: (millions) Statement of Operations Location Net Book Value (1) Pre-tax Impairment Proved Property Impairment - Delaware Basin Asset Impairments $ 3,613 $ 2,703 Leasehold Impairment - Delaware Basin Exploration Expense 1,915 1,385 Leasehold Impairment - Eagle Ford Shale Exploration Expense 100 100 Total Exploration Expense $ 2,015 $ 1,485 Goodwill Impairment - Noble Midstream Partners Goodwill Impairment $ 110 $ 110 Finance Lease Right-of-Use Asset Impairment Other Operating Expense, Net 88 40

Capitalized Exploratory Well _2

Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs (Tables)	3 Months Ended
	Mar. 31, 2020
Extractive Industries [Abstract]
Aging 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) March 31, 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 261 258 Capitalized Exploratory Well Costs, End of Period $ 291 $ 280 Number of Projects with Exploratory Well Costs That Have Been Capitalized for a Period Greater Than One Year Since Commencement of Drilling 5 5
Rollforward of Undeveloped Lease Costs	Changes in undeveloped leasehold costs are as follows: (millions) Three Months Ended March 31, 2020 Undeveloped Leasehold Costs, Beginning of Period $ 2,152 Additions to Undeveloped Leasehold Costs 2 Impairment (1) (1,485 ) Other (2 ) Undeveloped Leasehold Costs, End of Period $ 667 (1) Relates to impairments of undeveloped leasehold costs for unproved properties in the Delaware Basin and Eagle Ford Shale. See Note 2. Basis of Presentation and Note 4. Impairments .

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2020
Asset Retirement Obligation Disclosure [Abstract]
Changes in Asset Retirement Obligations	Changes in ARO are as follows: Three Months Ended March 31, (millions) 2020 2019 Asset Retirement Obligations, Beginning Balance $ 814 $ 880 Liabilities Incurred 3 2 Liabilities Settled (27 ) (27 ) Revisions of Estimates (8 ) — Accretion Expense 11 12 Asset Retirement Obligations, Ending Balance $ 793 $ 867

Debt (Tables)

Debt (Tables)	3 Months Ended
	Mar. 31, 2020
Debt Disclosure [Abstract]
Schedule of Debt	Debt consists of the following: March 31, 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 $ 1,000 1.92 % $ — — % Senior Notes and Debentures 5,884 (1 ) 5,884 (1 ) Finance Lease Obligations 203 — % 205 — % Total Noble Energy Debt, Excluding Noble Midstream Partners Debt 7,087 6,089 Noble Midstream Partners Noble Midstream Services Revolving Credit Facility, due March 9, 2023 750 2.16 % 595 3.11 % Noble Midstream Services Term Loan Credit Facility, due July 31, 2021 500 1.94 % 500 2.85 % Noble Midstream Services Term Loan Credit Facility, due August 23, 2022 400 1.82 % 400 2.74 % Total Noble Midstream Partners Debt 1,650 1,495 Total Debt 8,737 7,584 Net Unamortized Discounts and Debt Issuance Costs (64 ) (65 ) Total Debt, Net of Unamortized Discounts and Debt Issuance Costs 8,673 7,519 Less Amounts Due Within One Year Finance Lease Obligations (41 ) (42 ) Long-Term Debt Due After One Year $ 8,632 $ 7,477 (1) The Senior Notes and Debentures have weighted average interest rates of 4.93% for both March 31, 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: March 31, 2020 December 31, 2019 (millions) Carrying Amount Fair Value (1) Carrying Amount Fair Value Debt $ 8,534 $ 6,705 $ 7,379 $ 8,033 (1) As of March 31, 2020 , the difference between the carrying amount and the fair value is primarily due to increased spreads resulting from the current commodity price, supply and demand environment coupled with the COVID-19 pandemic .

Income Taxes (Tables)

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2020
Income Tax Disclosure [Abstract]
Income Tax Provision (Benefit)	Income tax expense (benefit) consists of the following: Three Months Ended March 31, (millions, except percentages) 2020 2019 Current $ 37 $ 16 Deferred (48 ) (100 ) Total Income Tax Benefit $ (11 ) $ (84 ) Effective Tax Rate 0.27 % 22.5 %

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
	Mar. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Unsettled Derivative Instruments	As of March 31, 2020 , we had entered into the following crude oil derivative instruments: Swaps Collars Settlement Period 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 Apr2020-Dec2020 Sold Calls NYMEX WTI 8,000 $ — $ 65.59 $ — $ — $ — Apr2020-Dec2020 Swaps NYMEX WTI 11,500 — 57.79 — — — Apr2020-Jun2020 Swaps NYMEX WTI 72,000 — 37.09 — — — Jul2020-Dec2020 Three-Way Collars NYMEX WTI 53,000 — — 10.00 25.00 37.20 Jul2020-Dec2020 Call Swaption NYMEX WTI 11,000 — 58.95 — — — 2020 Basis Swaps Midland (1) 15,000 (5.01 ) — — — — (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. As of March 31, 2020 , we had entered into the following natural gas liquid (NGL) derivative instruments: Swaps Settlement Period Type of Contract Index Bbls per Day Weighted Average Fixed Price Apr 2020-Sept 2020 Ethane Swaps Mont Belvieu 2,000 $ 7.77 Apr 2020-Sept 2020 Propane Swaps Mont Belvieu 5,000 21.04 Apr 2020-Sept 2020 Isobutane Swaps Mont Belvieu 1,000 25.36 Apr 2020-Sept 2020 Butane Swaps Mont Belvieu 1,500 24.31 As of March 31, 2020 , we had entered into the following natural gas derivative instruments: Swaps Collars Settlement Period 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 Apr2020-Dec2020 Swaps NYMEX HH 90,000 $ — $ 2.60 $ — $ — $ — Apr2020-Oct2020 Three-Way Collars NYMEX HH 40,000 — — 2.25 2.70 2.85 Apr2020-Dec2020 Sold Puts NYMEX HH 90,000 — — 2.15 — — 2020 Basis Swaps CIG (1) 139,000 (0.56 ) — — — — 2020 Basis Swaps WAHA (1) 49,500 (1.05 ) — — — — 2021 Swaps NYMEX HH 70,000 — 2.42 — — — 2021 Call Swaption NYMEX HH 70,000 — 2.42 — — — 2021 Basis Swaps CIG (1) 60,000 (0.52 ) — — — — 2021 Basis Swaps WAHA (1) 32,000 (0.71 ) — — — — (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.
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 March 31, 2020 December 31, 2019 Balance Sheet Location March 31, 2020 December 31, 2019 Other Current Assets $ 221 $ 14 Other Current Liabilities $ 59 $ 36 Other Noncurrent Assets — 1 Other Noncurrent Liabilities 3 1 Total $ 221 $ 15 $ 62 $ 37
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 March 31, (millions) 2020 2019 Cash (Received) Paid in Settlement of Commodity Derivative Instruments Crude Oil (1) $ (210 ) $ (9 ) NGL — — Natural Gas 2 (5 ) Total Cash Received in Settlement of Commodity Derivative Instruments (208 ) (14 ) Non-cash Portion of (Gain) Loss on Commodity Derivative Instruments Crude Oil (187 ) 223 NGL (10 ) — Natural Gas 16 3 Total Non-cash Portion of (Gain) Loss on Commodity Derivative Instruments (181 ) 226 (Gain) Loss on Commodity Derivative Instruments Crude Oil (397 ) 214 NGL (10 ) — Natural Gas 18 (2 ) Total (Gain) Loss on Commodity Derivative Instruments $ (389 ) $ 212 (1) During first quarter 2020, we monetized certain crude oil derivative instruments by settling the instruments prior to their original settlement dates and 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)	3 Months Ended
	Mar. 31, 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 March 31, (millions, except per share amounts) 2020 2019 Net Loss and Comprehensive Loss Attributable to Noble Energy $ (3,963 ) $ (313 ) Weighted Average Number of Shares Outstanding, Basic 479 478 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 Loss Per Share, Basic and Diluted $ (8.27 ) $ (0.65 ) Number of Antidilutive Stock Options, Shares of Restricted Stock, and Shares of Common Stock in Rabbi Trust Excluded from Calculation Above 16 15

Basis of Presentation - Perform

Basis of Presentation - Performance Obligation, Expected Timing (Details) - USD ($)	Mar. 31, 2020	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Natural Gas Revenues	$ 5,943,000,000
Price per barrel which trigger provision adjustments	50
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Natural Gas Revenues	407,000,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing		9 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	599,000,000
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	418,000,000
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	412,000,000
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	412,000,000
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	$ 3,695,000,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing

Basis of Presentation - Noncont

Basis of Presentation - Noncontrolling Interest (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Accumulated Other Comprehensive Income (Loss) [Line Items]
Goodwill impairment	$ 110	$ 0
Preferred stock dividend rate	6.50%
Non-controlling Interests
Accumulated Other Comprehensive Income (Loss) [Line Items]
Goodwill impairment	$ 72

Basis of Presentation - Stateme

Basis of Presentation - Statements of Operations Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Other Revenue
Revenue from Sales	$ 1,020	$ 1,052
Production Expense
Lease Operating Expense	138	151
Production and Ad Valorem Taxes	39	49
Gathering, Transportation and Processing Expense	95	102
Total	276	305
Exploration Expense
Leasehold Impairment	1,485	0
Seismic, Geological and Geophysical	4	5
Staff Expense	13	12
Other	2	7
Total	1,504	24
Other Operating Expense, Net
Finance Lease Right-of-Use Asset Impairment	40	0
Firm Transportation Exit Cost	0	92
Other, Net	4	25
Total	44	117
Other Revenue
Other Revenue
Revenue from Sales	1	41
(Loss) Income from Equity Method Investments and Other
Other Revenue
Revenue from Sales	(24)	17
Midstream Services Revenues – Third Party
Other Revenue
Revenue from Sales	25	24
Other Royalty Expense
Production Expense
Cost of Purchased Oil and Gas	4	$ 3
Exploration Expense
Total	$ 1,504

Basis of Presentation - Balance

Basis of Presentation - Balance Sheet Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Accounts Receivable, Net
Commodity Sales	$ 308	$ 446
Joint Interest Billings	136	164
Other	125	128
Current Expected Credit Losses	(7)	(8)
Total	562	730
Other Current Assets
Commodity Derivative Assets	221	14
Inventories, Materials and Supplies	68	59
Assets Held for Sale	1	14
Prepaid Expenses and Other Current Assets	63	61
Total	353	148
Other Noncurrent Assets
Equity Method Investments	1,249	1,066
Operating Lease Right of Use Assets	244	227
Customer-Related Intangible Assets, Net	270	278
Goodwill	0	110
Other Assets, Noncurrent	162	153
Total	1,925	1,834
Other Current Liabilities
Production and Ad Valorem Taxes	113	118
Asset Retirement Obligations	84	84
Interest Payable	80	74
Operating Lease Liabilities	95	88
Compensation and Benefits Payable	25	126
Other Liabilities, Current	254	229
Total	651	719
Other Noncurrent Liabilities
Deferred Compensation Liabilities	112	133
Asset Retirement Obligations	709	730
Operating Lease Liabilities	172	164
Firm Transportation Exit Cost Accrual	114	129
Other Liabilities, Noncurrent	199	222
Total	$ 1,306	1,378
Lease renewal term	5 years
Lease renewal	$ 28
Accumulated amortization	$ 70	$ 62

Basis of Presentation - Compone

Basis of Presentation - Components of Cash, Cash Equivalents and Restricted Cash (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2019	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Cash and Cash Equivalents	$ 1,397	$ 484	$ 528	$ 716
Restricted Cash	0	0	2	3
Cash, Cash Equivalents, and Restricted Cash	$ 1,397	$ 484	$ 530	$ 719

Segment Information - Operating

Segment Information - Operating Results by Segment (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019
Segment Reporting Information [Line Items]
Revenue from Sales	$ 1,020	$ 1,052
Lease Operating Expense	138	151
Production and Ad Valorem Taxes	39	49
Gathering, Transportation and Processing Expense	95	102
Total	276	305
Exploration Expense	1,504	24
Depreciation, Depletion and Amortization	492	508
Asset Impairments	2,703
Goodwill, Impairment Loss	110	0
(Gain) Loss on Commodity Derivative Instruments	(389)	212
(Loss) Income Before Income Taxes	(4,018)	(373)
Additions to Long-Lived Assets, Excluding Acquisitions	442	712
Additions to Equity Method Investments	153
Additions to Equity Method Investments	226	271
Property, Plant and Equipment, Net	13,221		$ 17,451
Intersegment Eliminations and Other
Segment Reporting Information [Line Items]
Revenue from Sales	(115)	(106)
Lease Operating Expense	(14)	(9)
Production and Ad Valorem Taxes	0	0
Gathering, Transportation and Processing Expense	(75)	(69)
Total	(89)	(78)
Depreciation, Depletion and Amortization	(9)	(7)
Asset Impairments	0
Goodwill, Impairment Loss	0
(Gain) Loss on Commodity Derivative Instruments	0	0
(Loss) Income Before Income Taxes	(11)	(14)
Additions to Long-Lived Assets, Excluding Acquisitions	(24)	(23)
Additions to Equity Method Investments	0
Additions to Equity Method Investments		0
Property, Plant and Equipment, Net	(225)		(223)
Corporate
Segment Reporting Information [Line Items]
Revenue from Sales	17	27
Lease Operating Expense	0	0
Production and Ad Valorem Taxes	0	0
Gathering, Transportation and Processing Expense	0	0
Total	0	0
Depreciation, Depletion and Amortization	13	15
Asset Impairments	0
Goodwill, Impairment Loss	0
(Gain) Loss on Commodity Derivative Instruments	0	0
(Loss) Income Before Income Taxes	(208)	(264)
Additions to Long-Lived Assets, Excluding Acquisitions	7	11
Additions to Equity Method Investments	0
Additions to Equity Method Investments		0
Property, Plant and Equipment, Net	171		216
United States | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	639	763
Lease Operating Expense	108	125
Production and Ad Valorem Taxes	37	47
Gathering, Transportation and Processing Expense	146	142
Total	295	317
Depreciation, Depletion and Amortization	419	439
Asset Impairments	2,703
Goodwill, Impairment Loss	0
(Gain) Loss on Commodity Derivative Instruments	(389)	188
(Loss) Income Before Income Taxes	(3,917)	(247)
Additions to Long-Lived Assets, Excluding Acquisitions	357	511
Additions to Equity Method Investments	0
Additions to Equity Method Investments		0
Property, Plant and Equipment, Net	7,641		11,859
United States | Noble Midstream
Segment Reporting Information [Line Items]
Revenue from Sales	218	165
Lease Operating Expense	1	1
Production and Ad Valorem Taxes	2	2
Gathering, Transportation and Processing Expense	21	29
Total	24	32
Depreciation, Depletion and Amortization	26	25
Asset Impairments	0
Goodwill, Impairment Loss	110
(Gain) Loss on Commodity Derivative Instruments	0	0
(Loss) Income Before Income Taxes	(31)	73
Additions to Long-Lived Assets, Excluding Acquisitions	43	66
Additions to Equity Method Investments	153
Additions to Equity Method Investments		271
Property, Plant and Equipment, Net	1,734		1,721
United States | Intersegment Eliminations and Other
Segment Reporting Information [Line Items]
Revenue from Sales	115	106
Eastern Mediterranean | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	189	118
Lease Operating Expense	13	10
Production and Ad Valorem Taxes	0	0
Gathering, Transportation and Processing Expense	3	0
Total	16	10
Depreciation, Depletion and Amortization	19	16
Asset Impairments	0
Goodwill, Impairment Loss	0
(Gain) Loss on Commodity Derivative Instruments	0	0
(Loss) Income Before Income Taxes	145	84
Additions to Long-Lived Assets, Excluding Acquisitions	31	132
Additions to Equity Method Investments	0
Additions to Equity Method Investments		0
Property, Plant and Equipment, Net	3,055		3,041
West Africa | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	72	85
Lease Operating Expense	30	24
Production and Ad Valorem Taxes	0	0
Gathering, Transportation and Processing Expense	0	0
Total	30	24
Depreciation, Depletion and Amortization	24	20
Asset Impairments	0
Goodwill, Impairment Loss	0
(Gain) Loss on Commodity Derivative Instruments	0	24
(Loss) Income Before Income Taxes	10	11
Additions to Long-Lived Assets, Excluding Acquisitions	19	5
Additions to Equity Method Investments	0
Additions to Equity Method Investments		0
Property, Plant and Equipment, Net	792		793
Other Int'l | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Lease Operating Expense	0	0
Production and Ad Valorem Taxes	0	0
Gathering, Transportation and Processing Expense	0	0
Total	0	0
Depreciation, Depletion and Amortization	0	0
Asset Impairments	0
Goodwill, Impairment Loss	0
(Gain) Loss on Commodity Derivative Instruments	0	0
(Loss) Income Before Income Taxes	(6)	(16)
Additions to Long-Lived Assets, Excluding Acquisitions	9	10
Additions to Equity Method Investments	0
Additions to Equity Method Investments		0
Property, Plant and Equipment, Net	53		$ 44
Oil, NGL and Gas Sales
Segment Reporting Information [Line Items]
Revenue from Sales	894	937
Oil, NGL and Gas Sales | Intersegment Eliminations and Other
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Oil, NGL and Gas Sales | Corporate
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Oil, NGL and Gas Sales | United States | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	614	749
Oil, NGL and Gas Sales | United States | Noble Midstream
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Oil, NGL and Gas Sales | Eastern Mediterranean | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	191	118
Oil, NGL and Gas Sales | West Africa | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	89	70
Oil, NGL and Gas Sales | Other Int'l | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Crude Oil Sales
Segment Reporting Information [Line Items]
Revenue from Sales	578	612
Crude Oil Sales | Intersegment Eliminations and Other
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Crude Oil Sales | Corporate
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Crude Oil Sales | United States | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	492	545
Crude Oil Sales | United States | Noble Midstream
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Crude Oil Sales | Eastern Mediterranean | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	1	1
Crude Oil Sales | West Africa | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	85	66
Crude Oil Sales | Other Int'l | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
NGL Sales
Segment Reporting Information [Line Items]
Revenue from Sales	62	96
NGL Sales | Intersegment Eliminations and Other
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
NGL Sales | Corporate
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
NGL Sales | United States | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	62	96
NGL Sales | United States | Noble Midstream
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
NGL Sales | Eastern Mediterranean | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
NGL Sales | West Africa | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
NGL Sales | Other Int'l | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Natural Gas Sales
Segment Reporting Information [Line Items]
Revenue from Sales	254	229
Natural Gas Sales | Intersegment Eliminations and Other
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Natural Gas Sales | Corporate
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Natural Gas Sales | United States | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	60	108
Natural Gas Sales | United States | Noble Midstream
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Natural Gas Sales | Eastern Mediterranean | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	190	117
Natural Gas Sales | West Africa | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	4	4
Natural Gas Sales | Other Int'l | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Cost of Purchased of Gas
Segment Reporting Information [Line Items]
Revenue from Sales	125	74
Cost of Purchased Oil and Gas	139	87
Firm Transportation Exit Cost		92
Cost of Purchased of Gas | Intersegment Eliminations and Other
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Cost of Purchased Oil and Gas	0	0
Firm Transportation Exit Cost		0
Cost of Purchased of Gas | Corporate
Segment Reporting Information [Line Items]
Revenue from Sales	17	27
Cost of Purchased Oil and Gas	31	42
Firm Transportation Exit Cost		92
Cost of Purchased of Gas | United States | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	25	14
Cost of Purchased Oil and Gas	28	14
Firm Transportation Exit Cost		0
Cost of Purchased of Gas | United States | Noble Midstream
Segment Reporting Information [Line Items]
Revenue from Sales	83	33
Cost of Purchased Oil and Gas	80	31
Firm Transportation Exit Cost		0
Cost of Purchased of Gas | Eastern Mediterranean | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Cost of Purchased Oil and Gas	0	0
Firm Transportation Exit Cost		0
Cost of Purchased of Gas | West Africa | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Cost of Purchased Oil and Gas	0	0
Firm Transportation Exit Cost		0
Cost of Purchased of Gas | Other Int'l | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Cost of Purchased Oil and Gas	0	0
Firm Transportation Exit Cost		0
Loss from Equity Method Investments and Other
Segment Reporting Information [Line Items]
Revenue from Sales	(24)	17
Loss from Equity Method Investments and Other | Intersegment Eliminations and Other
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Loss from Equity Method Investments and Other | Corporate
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Loss from Equity Method Investments and Other | United States | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Loss from Equity Method Investments and Other | United States | Noble Midstream
Segment Reporting Information [Line Items]
Revenue from Sales	(5)	2
Loss from Equity Method Investments and Other | Eastern Mediterranean | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	(2)	0
Loss from Equity Method Investments and Other | West Africa | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	(17)	15
Loss from Equity Method Investments and Other | Other Int'l | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Midstream Services Revenues – Third Party
Segment Reporting Information [Line Items]
Revenue from Sales	25	24
Midstream Services Revenues – Third Party | Intersegment Eliminations and Other
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Midstream Services Revenues – Third Party | Corporate
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Midstream Services Revenues – Third Party | United States | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Midstream Services Revenues – Third Party | United States | Noble Midstream
Segment Reporting Information [Line Items]
Revenue from Sales	25	24
Midstream Services Revenues – Third Party | United States | Intersegment Eliminations and Other
Segment Reporting Information [Line Items]
Revenue from Sales	0
Midstream Services Revenues – Third Party | Eastern Mediterranean | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Midstream Services Revenues – Third Party | West Africa | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Midstream Services Revenues – Third Party | Other Int'l | Operating Segments
Segment Reporting Information [Line Items]
Revenue from Sales	0	0
Other Royalty Expense
Segment Reporting Information [Line Items]
Cost of Purchased Oil and Gas	4	3
Exploration Expense	1,504
Other Royalty Expense | Intersegment Eliminations and Other
Segment Reporting Information [Line Items]
Cost of Purchased Oil and Gas	0	0
Exploration Expense	0
Other Royalty Expense | Corporate
Segment Reporting Information [Line Items]
Cost of Purchased Oil and Gas	0	0
Exploration Expense	0
Other Royalty Expense | United States | Operating Segments
Segment Reporting Information [Line Items]
Cost of Purchased Oil and Gas	4	3
Exploration Expense	1,494
Other Royalty Expense | United States | Noble Midstream
Segment Reporting Information [Line Items]
Cost of Purchased Oil and Gas	0	0
Exploration Expense	0
Other Royalty Expense | Eastern Mediterranean | Operating Segments
Segment Reporting Information [Line Items]
Cost of Purchased Oil and Gas	0	0
Exploration Expense	2
Other Royalty Expense | West Africa | Operating Segments
Segment Reporting Information [Line Items]
Cost of Purchased Oil and Gas	0	0
Exploration Expense	3
Other Royalty Expense | Other Int'l | Operating Segments
Segment Reporting Information [Line Items]
Cost of Purchased Oil and Gas	0	$ 0
Exploration Expense	$ 5

Impairments (Details)

Impairments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Property, Plant and Equipment [Line Items]
Fair value of proved properties	$ 910
Fair value of unproved properties	530
Asset impairment charges	4,100
Pre-tax Impairment	2,703
Goodwill impairment	110	$ 0
Finance Lease Right-of-Use Asset Impairment	40	$ 0
Leasehold Impairment
Property, Plant and Equipment [Line Items]
Net Book Value	2,015
Pre-tax Impairment	1,485
Delaware Basin | Leasehold Impairment
Property, Plant and Equipment [Line Items]
Net Book Value	1,915
Pre-tax Impairment	1,385
Eagle Ford Shale | Leasehold Impairment
Property, Plant and Equipment [Line Items]
Net Book Value	100
Pre-tax Impairment	100
Goodwill
Property, Plant and Equipment [Line Items]
Net Book Value	110
Goodwill impairment	110
Finance Lease Right-of-Use Asset Impairment
Property, Plant and Equipment [Line Items]
Net Book Value	88
Finance Lease Right-of-Use Asset Impairment	40
Non-controlling Interests
Property, Plant and Equipment [Line Items]
Goodwill impairment	72
Non-controlling Interests | Goodwill
Property, Plant and Equipment [Line Items]
Pre-tax Impairment	72
Parent Company | Goodwill
Property, Plant and Equipment [Line Items]
Pre-tax Impairment	$ 38

Acquisitions, Divestitures an_2

Acquisitions, Divestitures and Equity Method Investments - Narrative (Details) a in Thousands, $ in Millions	1 Months Ended		3 Months Ended
	Dec. 31, 2019USD ($)	Feb. 28, 2019USD ($)a	Mar. 31, 2020USD ($)	Mar. 31, 2019USD ($)	Feb. 29, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions to equity method investments			$ 226	$ 271
Cash consideration	$ 1,066		1,249
Saddlehorn Pipeline Company, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions to equity method investments			160
Saddlehorn Pipeline Company, LLC | Noble Midstream
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions to equity method investments			87
EPIC Y-Grade, LP
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions to equity method investments			14
Business Combination, Step Acquisition, Equity Interest in Acquiree, Percentage				15.00%
EPIC Y-Grade, LP | Noble Midstream
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash consideration				$ 227
EPIC Crude Holdings, LP
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions to equity method investments			33
Business Combination, Step Acquisition, Equity Interest in Acquiree, Percentage				30.00%
EPIC Propane
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions to equity method investments	$ 2
Delaware Crossing JV
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions to equity method investments			17
Delaware Crossing JV | Noble Midstream
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions to equity method investments			$ 38
Disposed by sale | Reeves County Assets
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proved and unproved non-core acreage sold (in acres) | a		13
Proceeds from divestitures		$ 131
Black Diamond Gathering
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity method investment, ownership percent					20.00%
Black Diamond Gathering | Black Diamond Gathering LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percent			54.40%

Capitalized Exploratory Well _3

Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs - Aging of Capitalized Exploratory Well Costs (Details) $ in Millions	Mar. 31, 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	261	258
Capitalized Exploratory Well Costs, End of Period	$ 291	$ 280
Number of Projects with Exploratory Well Costs That Have Been Capitalized for a Period Greater Than One Year Since Commencement of Drilling | project	5	5

Capitalized Exploratory Well _4

Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs - Rollforward of Undeveloped Leasehold Costs (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020USD ($)
Proved Developed and Undeveloped Reserves [Roll Forward]
Undeveloped Leasehold Costs, Beginning of Period	$ 2,152
Additions to Undeveloped Leasehold Costs	2
Impairment (1)	(1,485)
Other	(2)
Undeveloped Leasehold Costs, End of Period	$ 667

Capitalized Exploratory Well _5

Capitalized Exploratory Well Costs and Undeveloped Leasehold Costs - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020USD ($)
Delaware Basin
Projects with Exploratory Well Costs Capitalized for More than One Year Since The Commencement of Drilling [Line Items]
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 [Line Items]
Capitalized undeveloped leasehold cost	80
Other Int'l
Projects with Exploratory Well Costs Capitalized for More than One Year Since The Commencement of Drilling [Line Items]
Capitalized undeveloped leasehold cost	$ 57

Asset Retirement Obligations -

Asset Retirement Obligations - ARO Activity (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligations, Beginning Balance	$ 814	$ 880
Liabilities Incurred	3	2
Liabilities Settled	(27)	(27)
Revisions of Estimates	(8)	0
Accretion Expense	11	12
Asset Retirement Obligations, Ending Balance	$ 793	$ 867

Asset Retirement Obligations _2

Asset Retirement Obligations - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Reserve Quantities [Line Items]
Liabilities settled	$ 27	$ 27
DJ Basin
Reserve Quantities [Line Items]
Liabilities settled	$ 21	$ 27

Debt - Summary of Debt (Details

Debt - Summary of Debt (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Total Debt	$ 8,737	$ 7,584
Net Unamortized Discounts and Debt Issuance Costs	(64)	(65)
Total Debt	8,673	7,519
Finance Lease Obligations	(41)	(42)
Long-Term Debt Due After One Year	8,632	7,477
Noble Midstream Services Revolving Credit Facility
Debt Instrument [Line Items]
Available borrowing capacity	400	$ 555
Senior Notes and Debentures
Debt Instrument [Line Items]
Weighted average interest rate		4.93%
Noble Energy
Debt Instrument [Line Items]
Finance Lease Obligations	$ 203	$ 205
Finance Lease Obligations, Interest Rate	0.00%	0.00%
Total Debt	$ 7,087	$ 6,089
Noble Energy | Revolving Credit Facility, due March 9, 2023
Debt Instrument [Line Items]
Debt	$ 1,000	$ 0
Interest Rate	1.92%	0.00%
Noble Energy | Senior Notes and Debentures
Debt Instrument [Line Items]
Debt	$ 5,884	$ 5,884
Noble Midstream Partners
Debt Instrument [Line Items]
Total Debt	1,650	1,495
Noble Midstream Partners | Revolving Credit Facility | Noble Midstream Services Revolving Credit Facility, due March 9, 2023
Debt Instrument [Line Items]
Debt	$ 750	$ 595
Interest Rate	2.16%	3.11%
Noble Midstream Partners | Revolving Credit Facility | Noble Midstream Services Term Loan Credit Facility, due July 31, 2021
Debt Instrument [Line Items]
Debt	$ 500	$ 500
Interest Rate	1.94%	2.85%
Noble Midstream Partners | Revolving Credit Facility | Noble Midstream Services Term Loan Credit Facility, due August 23, 2022
Debt Instrument [Line Items]
Debt	$ 400	$ 400
Interest Rate	1.82%	2.74%

Debt - Narrative (Details)

Debt - Narrative (Details) - USD ($)	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Total borrowing capacity	$ 4,000,000,000
Commercial Paper
Debt Instrument [Line Items]
Proceeds from Revolving Credit Facilities	1,000,000,000
Available borrowing capacity	3,000,000,000	$ 4,000,000,000
Revolving Credit Facility | Noble Midstream | Noble Midstream Services Term Loan Credit Facility, due August 23, 2022
Debt Instrument [Line Items]
Debt	$ 400,000,000	$ 400,000,000
Interest Rate	1.82%	2.74%

Debt - Fair Value of Debt (Deta

Debt - Fair Value of Debt (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Carrying Amount
Debt Instrument [Line Items]
Debt	$ 8,534	$ 7,379
Fair Value
Debt Instrument [Line Items]
Debt	$ 6,705	$ 8,033

Income Taxes - Components of In

Income Taxes - Components of Income Tax (Benefit) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Income Tax Disclosure [Abstract]
Current	$ 37	$ 16
Deferred	(48)	(100)
Total Income Tax Benefit	$ (11)	$ (84)
Effective Tax Rate	0.27%	22.50%

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)	Mar. 31, 2020bbl / d$ / bbl$ / MMBTUMMBTU / d
Crude Oil | NYMEX WTI - Sold Calls 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | bbl / d	8,000
Weighted Average Fixed Price ($ per bbl)	65.59
Crude Oil | NYMEX WTI - Swaps 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | bbl / d	11,500
Crude Oil | NYMEX WTI - Swaps 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | bbl / d	72,000
Weighted Average Fixed Price ($ per bbl)	37.09
Crude Oil | NYMEX WTI - Three-Way Collars 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | bbl / d	53,000
Weighted Average Short Put Price ($ per bbl)	10
Weighted Average Floor Price ($ per bbl)	25
Weighted Average Ceiling Price ($ per bbl)	37.20
Crude Oil | NYMEX WTI - Call Swaption 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | bbl / d	11,000
Weighted Average Fixed Price ($ per bbl)	58.95
Crude Oil | Basis Swaps 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | bbl / d	15,000
Natural Gas Liquids Contract | Ethane Swaps 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | bbl / d	2,000
Weighted Average Fixed Price ($ per bbl)	7.77
Natural Gas Liquids Contract | Propane Swaps 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | bbl / d	5,000
Weighted Average Fixed Price ($ per bbl)	21.04
Natural Gas Liquids Contract | Isobutane Swaps 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | bbl / d	1,000
Weighted Average Fixed Price ($ per bbl)	25.36
Natural Gas Liquids Contract | Butane Swaps 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | bbl / d	1,500
Weighted Average Fixed Price ($ per bbl)	24.31
Natural Gas Contract | NYMEX HH - Swaps 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | MMBTU / d	90,000
Natural Gas Contract | NYMEX HH Three-Way Collars 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | MMBTU / d	40,000
Weighted Average Short Put Price ($ per bbl) | $ / MMBTU	2.25
Weighted Average Floor Price ($ per bbl) | $ / MMBTU	2.70
Weighted Average Ceiling Price ($ per bbl) | $ / MMBTU	2.85
Natural Gas Contract | NYMEX HH - Sold Puts 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | MMBTU / d	90,000
Natural Gas Contract | CIG - Basis Swaps 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | MMBTU / d	139,000
Natural Gas Contract | WAHA - Basis Swaps 2020
Derivative [Line Items]
Bbls Per Day (Bbls per day) | MMBTU / d	49,500
Natural Gas Contract | Swaps 2021
Derivative [Line Items]
Bbls Per Day (Bbls per day) | MMBTU / d	70,000
Natural Gas Contract | Call Swaption 2021
Derivative [Line Items]
Bbls Per Day (Bbls per day) | MMBTU / d	70,000
Natural Gas Contract | CIG - Basis Swaps 2021
Derivative [Line Items]
Bbls Per Day (Bbls per day) | MMBTU / d	60,000
Natural Gas Contract | WAHA - Basis Swaps 2021
Derivative [Line Items]
Bbls Per Day (Bbls per day) | MMBTU / d	32,000
Swaps | Crude Oil | NYMEX WTI - Swaps 2020
Derivative [Line Items]
Weighted Average Fixed Price ($ per bbl)	57.79
Swaps | Crude Oil | Basis Swaps 2020
Derivative [Line Items]
Weighted Average Differential ($ per bbl)	(5.01)
Swaps | Natural Gas Contract | NYMEX HH - Swaps 2020
Derivative [Line Items]
Weighted Average Fixed Price ($ per bbl) | $ / MMBTU	2.60
Swaps | Natural Gas Contract | CIG - Basis Swaps 2020
Derivative [Line Items]
Weighted Average Differential ($ per bbl) | $ / MMBTU	(0.56)
Swaps | Natural Gas Contract | WAHA - Basis Swaps 2020
Derivative [Line Items]
Weighted Average Differential ($ per bbl) | $ / MMBTU	(1.05)
Swaps | Natural Gas Contract | Swaps 2021
Derivative [Line Items]
Weighted Average Fixed Price ($ per bbl) | $ / MMBTU	2.42
Swaps | Natural Gas Contract | Call Swaption 2021
Derivative [Line Items]
Weighted Average Fixed Price ($ per bbl) | $ / MMBTU	2.42
Swaps | Natural Gas Contract | CIG - Basis Swaps 2021
Derivative [Line Items]
Weighted Average Differential ($ per bbl) | $ / MMBTU	(0.52)
Swaps | Natural Gas Contract | WAHA - Basis Swaps 2021
Derivative [Line Items]
Weighted Average Differential ($ per bbl) | $ / MMBTU	(0.71)
Sold Puts | Natural Gas Contract | NYMEX HH - Sold Puts 2020
Derivative [Line Items]
Weighted Average Short Put Price ($ per bbl) | $ / MMBTU	2.15

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
	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value	$ 221		$ 15
Derivative Liability, Fair Value	62		37
Total Cash Received in Settlement of Commodity Derivative Instruments	(208)	$ (14)
Total Non-cash Portion of (Gain) Loss on Commodity Derivative Instruments	(181)	226
Total (Gain) Loss on Commodity Derivative Instruments	(389)	212
Proceeds from derivative settlement	160
Other Current Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value	221		14
Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value	59		36
Other Noncurrent Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value	0		1
Other Noncurrent Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value	3		$ 1
Crude Oil
Derivatives, Fair Value [Line Items]
Total Cash Received in Settlement of Commodity Derivative Instruments	(210)	(9)
Total Non-cash Portion of (Gain) Loss on Commodity Derivative Instruments	(187)	223
Total (Gain) Loss on Commodity Derivative Instruments	(397)	214
NGL
Derivatives, Fair Value [Line Items]
Total Cash Received in Settlement of Commodity Derivative Instruments	0	0
Total Non-cash Portion of (Gain) Loss on Commodity Derivative Instruments	(10)	0
Total (Gain) Loss on Commodity Derivative Instruments	(10)	0
Natural Gas
Derivatives, Fair Value [Line Items]
Total Cash Received in Settlement of Commodity Derivative Instruments	2	(5)
Total Non-cash Portion of (Gain) Loss on Commodity Derivative Instruments	16	3
Total (Gain) Loss on Commodity Derivative Instruments	$ 18	$ (2)

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
	Mar. 31, 2020	Mar. 31, 2019
Earnings Per Share [Abstract]
Net Loss and Comprehensive Loss Attributable to Noble Energy	$ (3,963)	$ (313)
Weighted Average, Number of Shares Outstanding, Basic (in shares)	479	478
Incremental Shares from Assumed Conversion of Dilutive Stock Options, Restricted Stock, and Shares of Common Stock in Rabbi Trust (in shares)	0	0
Weighted Average, Number of Shares Outstanding, Diluted (in shares)	479	478
Basic and Diluted ($ per share)	$ (8.27)	$ (0.65)
Number of Antidilutive Stock Options, Shares of Restricted Stock, and Shares of Common Stock in Rabbi Trust Excluded from Calculation Above	16	15