Equinor ASA (EQNR) 20-F 18 Mar 22 2021 FY Annual report (foreign) Financial data

Cover page

Cover page	12 Months Ended
	Dec. 31, 2021shares
Document and Entity Information [abstract]
Document Type	20-F
Document Annual Report	true
Document Period End Date	Dec. 31, 2021
Entity Interactive Data Current	Yes
Entity Incorporation State Country Code	Q8
Entity File Number	1-15200
Entity Registrant Name	Equinor ASA
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Address Address Line 1	Forusbeen 50
Entity Address City Or Town	Stavanger
Entity Address Postal Zip Code	N-4035
Entity Address Country	NO
Entity Filer Category	Large Accelerated Filer
Entity Voluntary Filers	No
Entity Well Known Seasoned Issuer	Yes
Security 12g Title	None
Entity Common Stock Shares Outstanding	3,232,116,311
Document Transition Report	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0001140625
Document Registration Statement	false
Amendment Flag	false
Document Accounting Standard	International Financial Reporting Standards
Shell Company Report	false
Icfr Auditor Attestation Flag	true
Auditor firm id	1572
Auditor Name	Ernst & Young AS
Auditor Location	Stavanger, Norway
American Depositary Shares [member]
Document and Entity Information [abstract]
Trading Symbol	EQNR
Security 12g Title	American Depositary Shares
Security Exchange Name	NYSE
Ordinary shares, nominal value of NOK 2.50 each [member]
Document and Entity Information [abstract]
Trading Symbol	EQNR
Security 12g Title	Ordinary shares, nominal value of NOK 2.50
Security Exchange Name	NYSE
Business Contact [member]
Document and Entity Information [abstract]
Contact Personnel Name	Ulrica Fearn
Entity Address Address Line 1	Forusbeen 50
Entity Address City Or Town	Stavanger
Entity Address Postal Zip Code	N-4035
Entity Address Country	NO
City Area Code	47
Local Phone Number	5199-0000
Contact Personnel Fax Number	5199-0050

CONSOLIDATED STATEMENT OF INCOM

CONSOLIDATED STATEMENT OF INCOME - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CONSOLIDATED STATEMENT OF INCOME [Abstract]
Revenues	$ 88,744	$ 45,753	$ 62,911
Net income/(loss) from equity accounted investments	259	53	164
Other Income	1,921	12	1,283
Total revenues and other income	90,924	45,818	64,357
Purchases (net of inventory variation)	(35,160)	(20,986)	(29,532)
Operating expenses	(8,598)	(8,831)	(9,660)
Selling, general and administrative expenses	(780)	(706)	(809)
Depreciation, amortisation and net impairment losses	(11,719)	(15,235)	(13,204)
Exploration expenses	(1,004)	(3,483)	(1,854)
Total operating expenses	(57,261)	(49,241)	(55,058)
Net operating income/(loss)	33,663	(3,423)	9,299
Interest expenses and other financial expenses	(1,223)	(1,392)	(1,450)
Other financial items	(857)	556	1,443
Net financial items	(2,080)	(836)	(7)
Income/(loss) before tax	31,583	(4,259)	9,292
Income tax	(23,007)	(1,237)	(7,441)
Net income/(loss)	8,576	(5,496)	1,851
Attributable to equity holders of the company	8,563	(5,510)	1,843
Attributable to non-controlling interests	$ 14	$ 14	$ 8
Basic earnings per share (in USD)	$ 2.64	$ (1.69)	$ 0.55
Diluted earnings per share (in USD)	$ 2.63	$ (1.69)	$ 0.55
Weighted average number of ordinary shares outstanding (in millions)	3,245	3,269	3,326
Weighted average number of ordinary shares outstanding, diluted (in millions)	3,254	3,277	3,334

CONSOLIDATED STATEMENT OF COMPR

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Consolidated statements of comprehensive income [Abstrct]
Net income/(loss)		$ 8,576	$ (5,496)	$ 1,851
Actuarial gains (losses) on defined benefit pension plans		147	(106)	427
Income tax effect on income and expenses recognised in OCI	[1]	(35)	19	(98)
Items that will not be reclassified to the Consolidated statement of income		111	(87)	330
Foreign currency translation effect		(1,052)	1,064	(51)
Share of OCI from equity accounted investments		0	0	44
Items that may subsequently be reclassified to the Consolidated statement of income		(1,052)	1,064	(7)
Other comprehensive income/(loss)		(940)	977	323
Total comprehensive income/(loss)		7,636	(4,519)	2,174
Attributable to the equity holders of the company		7,622	(4,533)	2,166
Attributable to non-controlling interests		$ 14	$ 14	$ 8
[1]	1) Other Comprehensive Income (OCI).

CONSOLIDATED BALANCE SHEET

CONSOLIDATED BALANCE SHEET - USD ($) $ in Millions		Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Noncurrent assets [abstract]
Property, plant and equipment		$ 62,075		$ 68,508		$ 71,751
Intangible assets		6,452		8,149		10,738
Equity accounted investments		2,686		2,262		1,442
Deferred tax assets		6,259		4,974		3,881
Pension assets		1,449		1,310		1,093
Derivative financial instruments		1,265		2,476		1,365
Financial investments		3,346		4,083		3,600
Prepayments and financial receivables		1,087		861		1,214
Total non-current assets		84,618		92,623		95,083
Current assets [abstract]
Inventories		3,395		3,084		3,363
Trade and other receivables		17,927		8,232		8,233
Derivative financial instruments		5,131		886		578
Financial investments		21,246		11,865		7,426
Cash and cash equivalents		14,126		6,757		5,177
Total current assets		61,826		30,824		24,778
Assets classified as held for sale		676		1,362		0
Total assets		147,120		124,809		119,861
Equity [abstract]
Shareholders equity		39,010		33,873		41,139
Non-controlling interests		14		19		20
Total equity		39,024		33,892		41,159
Noncurrent liabilities [abstract]
Finance debt		27,404	[1]	29,118	[1]	21,754
Lease liabilities		2,449	[1]	3,220	[1]	3,191
Deferred tax liabilities		14,037		11,224		9,410
Pension liabilities		4,403		4,292		3,867
Provisions and other liabilities	[1]	19,899		22,568		19,750
Derivative financial instruments		767		676		1,173
Total non-current liabilities		68,959		71,097		59,144
Current liabilities [abstract]
Trade, other payables and provisions		14,310		10,510		10,450
Current tax payable		13,119		1,148		3,699
Finance debt		5,273	[1]	4,591	[1]	2,939
Lease liabilities		1,113	[1]	1,186	[1]	1,148
Dividend payable		582		357		859
Derivative financial instruments		4,609		1,710		462
Total current liabilities		39,005		19,502		19,557
Liabilities directly associated with the assets classified as held for sale		132		318		0
Total liabilities		108,096		90,917		78,702
Total equity and liabilities		$ 147,120		$ 124,809		$ 119,861
[1]	1) Restated 1 January 2020 and 31 December and note 21 Provisions and other liabilities.

CONSOLIDATED STATEMENT OF CHANG

CONSOLIDATED STATEMENT OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Share capital [member]	Addiitonal paid in capital [member]	Retained earnings [member]	Foreign currency translation reserve [member]	OCI from equity accounted investments [member]	Shareholders's equity [member]	Non-controling interest [member]
Equity beginning balance at Dec. 31, 2018	$ 42,990	$ 1,185	$ 8,247	$ 38,790	$ (5,206)	$ (44)	$ 42,970	$ 19
Net income/(loss)	1,851			1,843			1,843	8
Other comprehensive income/(loss)	323			330	(51)	44	323
Total comprehensive income/(loss)	2,174
Dividends	(3,453)			(3,453)			(3,453)
Share buy-back	(500)		(500)				(500)
Other equity transactions	(52)		(15)	(29)			(44)	(7)
Equity ending balance at Dec. 31, 2019	41,159	1,185	7,732	37,481	(5,258)	0	41,139	20
Net income/(loss)	(5,496)			(5,510)			(5,510)	14
Other comprehensive income/(loss)	977			(87)	1,064	0	977
Total comprehensive income/(loss)	(4,519)
Dividends	(1,833)			(1,833)			(1,833)
Share buy-back	(890)	(21)	(869)				(890)
Other equity transactions	(25)		(11)	0			(11)	(15)
Equity ending balance at Dec. 31, 2020	33,892	1,164	6,852	30,050	(4,194)	0	33,873	19
Net income/(loss)	8,576			8,563			8,563	14
Other comprehensive income/(loss)	(940)			111	(1,052)	0	(940)
Total comprehensive income/(loss)	7,636
Dividends	(2,041)			(2,041)			(2,041)
Share buy-back	(429)	0	(429)				(429)
Other equity transactions	(33)		(15)	0			(15)	(18)
Equity ending balance at Dec. 31, 2021	$ 39,024	$ 1,164	$ 6,408	$ 36,683	$ (5,245)	$ 0	$ 39,010	$ 14

CONSOLIDATED STATEMENT OF CASH

CONSOLIDATED STATEMENT OF CASH FLOWS - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Cash flows from (used in) operating activities [abstract]
Income/(loss) before tax		$ 31,583		$ (4,259)		$ 9,292
Depreciation, amortisation and net impairment losses		11,719		15,235		13,204
Exploration expenditures written off		171		2,506		777
(Gains) losses on foreign currency transactions and balances		(47)		646		(224)
(Gains) losses on sales of assets and businesses		(1,519)		18		(1,187)
(Increase) decrease in other items related to operating activities	[1]	106		918		1,016
(Increase) decrease in net derivative financial instruments		539		(451)		(595)
Interest received		96		162		215
Interest paid		(698)		(730)		(723)
Cash flows provided by operating activities before taxes paid and working capital items		41,950		14,045		21,776
Taxes paid		(8,588)		(3,134)		(8,286)
(Increase) decrease in working capital		(4,546)		(524)		259
Cash flows provided by operating activities		28,816		10,386		13,749
Cash flows from (used in) investing activities [abstract]
Cash used in business combinations	[2]	(111)		0		(2,274)
Capital expenditures and investments		(8,040)		(8,476)		(10,204)
(Increase) decrease in financial investments	[3]	(9,951)		(3,703)		(1,012)
(Increase) decrease in derivatives financial instruments		(1)		(620)		298
(Increase)/decrease in other interest bearing items		28		202		(10)
Proceeds from sale of assets and businesses		1,864		505		2,608
Cash flows used in investing activities		(16,211)		(12,092)		(10,594)
Cash flows from (used in) financing activities [abstract]
New finance debt		0		8,347		984
Repayment of finance debt	[4]	(2,675)		(2,055)		(1,314)
Repayment of lease liabilities	[4]	(1,238)		(1,277)		(1,104)
Dividend paid		(1,797)		(2,330)		(3,342)
Share buy-back		(321)		(1,059)		442
Net current finance debt and other financing activities		1,195		1,365		(277)
Cash flows provided by (used in) financing activities		(4,836)		2,991		(5,496)
Net increase (decrease) in cash and cash equivalents		7,768		1,285		(2,341)
Foreign currency translation effects		(538)		294		(38)
Cash and cash equivalents at the beginning of the period (net of overdraft)		6,757	[5]	5,177	[5]	7,556
Cash and cash equivalents at the end of the period (net of overdraft)	[5]	$ 13,987		$ 6,757		$ 5,177
[1]	Full year 2021 includes redetermination settlement for the liabilities and contingent assets.
[2]	Net after cash and cash equivalents acquired.
[3]	Includes sale of Lundin shares in 2020.
[4]	Repayment of lease liabilities are separated from the line
[5]	At 31 December 2021 cash and cash equivalents 140 cash equivalents net overdraft were zero .

CONSOLIDATED STATEMENT OF CAS_2

CONSOLIDATED STATEMENT OF CASH FLOWS - (Parenthectical) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash and cash equivalents includes: [abstract]
Bank overdrafts	$ 140,000,000	$ 0	$ 0
Interest paid [abstract]
Capitalised interest	334,000,000	308,000,000	480,000,000
Total interest paid	$ 1,032,000	$ 1,038,000	$ 1,203,000

Organisation

Organisation	12 Months Ended
	Dec. 31, 2021
Organisation [Abstract]
Disclosure of notes and other explanatory information [text block]	1 Organisation Equinor ASA , originally Den Norske Stats Oljeselskap AS, was founded in 1972 and is incorporated Norway . The address of its registered office is Forusbeen 50, N-4035 Stavanger, Norway . Equinor ASA’s shares are listed on the Oslo Børs (OSL, Norway) and the New York Stock Exchange (NYSE, USA). The Equinor group's business consists principally of the exploration, production, transportation, refining and marketing of petroleum and petroleum-derived products and other forms of energy. All the Equinor group's oil and gas activities and net assets on the Norwegian continental shelf 100% owned operating subsidiary. The Consolidated financial statements of Equinor for the full year 2021 were authorised for issue the board of directors on 8 March 2022.

Consequences of initiatives to

Consequences of initiatives to limit climate changes	12 Months Ended
	Dec. 31, 2021
Consequences of initiatives to limit climate changes [abstract]
Consequences of initiatives to limit climate changes [text block]	3 Consequences of initiatives to limit climate changes Equinor’s ambitions and our strategy Climate change and reaching the goals set out in the Paris Agreement represent fundamental COP26 Glasgow Climate Pact, achieving the most ambitious goals of the Paris Agreement reductions in global greenhouse gas emissions. This includes reducing global carbon dioxide 2010 levels, and to net zero around mid-century. Equinor’s ambition is to be a leading company in the energy transition and to become a net-zero company by 2050, including emissions from production through to final to create value as a leader in the energy transition by pursuing high-value growth in renewables carbon solutions at the same time as it optimises its oil and gas portfolio. Assessment of risks arising from climate change and the energy transition Climate changes and a transition to a lower carbon economy will affect Equinor’s business factors. Equinor’s climate roadmap and all of our climate-related ambitions are a response to these climate change. ● oil and gas. Increased demand for and improved cost competitiveness of renewable energy, and innovation and technology changes supporting the further development and use of renewable energy and low-carbon technologies, and opportunities for Equinor. ● Equinor’s operations. Examples of physical parameters that could impact Equinor’s effects like increasing frequency and severity of extreme weather events, and chronic effects like rising sea level, changes in currents and reduced water availability. Unexpected changes in meteorological parameters, such as average wind speed, can also affect renewable power generation outputs, resulting in performance above or below expectations. ● gas emissions, such as changes in carbon costs and taxes, emission standards or energy subsidy regulations and policies could impact Equinor's financial outlook, including the value of through changes in consumer behaviour or technology developments. ● producers, as well as a more negative perception of the oil and gas industry. This could lead to increased litigation-related costs and poor reputation could affect Equinor’s license to operate as well as the ability to competences. ● low carbon industries and hamper the transition into a broader energy company. Competitive auctions/tenders where prices don’t allow absorption of higher costs may increase the exposure to inflation risk. This is also relevant income have been locked in before the final investment decision. There is also a risk of increased producers. Certain lenders have recently indicated that they will direct or restrict their lending parameters. Effects on estimation uncertainty The effects of the initiatives to limit climate changes and the potential impact of the energy transition economic assumptions in our estimations of future cash flows. The results of the development which Equinor’s operations will be affected by them, are sources of uncertainty. Estimating global energy demand and commodity prices towards 2050 is a challenging task, as this comprises assessing the future development change, taxation, tax on emissions, production limits and other important factors. The assumptions materialise in different outcomes from the current projected scenarios. This could result in significant changes estimates, such as economic useful life (affects depreciation period and timing of asset retirement obligations) and value-in-use calculations (affects impairment assessments). Equinor’s commodity price assumptions applied in value-in-use impairment testing, are and based on management’s best estimate of the development of relevant current circumstances and the likely such circumstances. This price-set is currently not equal to a price-set required to achieve described in the WEO Sustainability Development Scenario, or the Net Zero Emissions trajectory of how the world acts with regards to implementing actions in accordance with the goals in the depending on the detailed characteristics of such a trajectory, have a negative impact on the valuation of Equinor’s property, plant and equipment in total. A calculation of a possible effect of using the prices (including CO 2 o C compatible Net Zero Emission by 2050 Scenario as estimated by the International Energy Agency (IEA) could result in an impairment 7 tax. This illustrative impairment sensitivity is based on a simplified model and limitations further described in equipment. CO 2 -related cost Equinor expects greenhouse gas emission costs to increase from current levels and to have global tax on CO 2 Equinor’s internal carbon price applied to all potential new projects and investments, currently set 58 towards 100 decisions following Equinor’s strategy and commitments to the energy transition. Climate considerations are included in the impairment calculations directly by estimating the CO 2 the expected effect of climate change is also included in the estimated commodity prices where supply and demand The CO 2 Impairment calculations are based on best estimate assumptions. To reflect that carbon will have a cost for all our assets, the current best estimate is considered to be EU ETS for countries outside EU where carbon is not has not established specific estimates. The EU ETS price has increased significantly from 56 remain high, in the region of 80 65 27.5 EUR/tonne) in 2030 and thereafter increasing to 100 41 Norway’s Climate Action Plan for the period 2021-2030 (Meld. St 13 (2020-2021)) which assumes 2 total of EU ETS + Norwegian CO 2 2,000 upstream assets. Total expensed CO 2 2 related to activities on the Norwegian Continental Shelf (Equinor’s share in Norway owned by Equinor amounts to USD 428 268 Upstream oil & gas (stranded assets) The transition to renewable energy, technological development and reduction in global demand for carbon-based energy, may have a negative impact on the future profitability of investments in upstream oil and gas assets, in particular lives, projects in an early development phase and undeveloped assets controlled by Equinor. Equinor seeks to mitigate this risk by focusing on improving the resilience of the existing upstream portfolio, maximising the efficiency of our infrastructure on the Norwegian Continental Shelf and optimising our high-quality international portfolio. Equinor will also continue resources with a focus on mature areas that can make use of existing infrastructure to minimise During the transition, Equinor will allocate less of our capital budget to oil and gas in the volume of production over time. Equinor’s plans to become a net-zero company by 2050 have not additional assets being triggered for impairment or earlier cessation of production as of year-end Any future exploration may be restricted by regulations, market and strategic considerations. Provided would deteriorate to such an extent that undeveloped assets controlled by Equinor should not materialize, comprise the intangible assets Oil and Gas prospects, signature bonuses and the capitalised value of USD 4.6 Timing of Asset Retirement Obligations (ARO) If the business cases of Equinor’s oil and gas producing assets should change, this could affect the timing of our asset retirement obligations. A shorter production period, accelerating the time for assets need to be removed after ended production, will increase the carrying value of the liability. The effect of performing removal five years earlier than currently scheduled, is estimated to increase the liability by USD 0.2 liabilities for more information regarding Equinor’s ARO.

Segments

Segments	12 Months Ended
	Dec. 31, 2021
Disclosure of operating segments [abstract]
Disclosure of entity's operating segments [text block]	4 Segments As from 1 June 2021 Equinor’s operations are managed through the following Production Norway (EPN), Exploration & Production International (EPI), Exploration & Production USA Midstream & Processing (MMP), Renewables (REN), Projects, Drilling and Procurement (PDP) and (TDI) and Corporate staff and functions. The main change in the organisational corporate structure compared to previous periods is that the & Production Brazil is merged into the operating segment Exploration & Production International. Exploration is divided and merged into Exploration & Production Norway, Exploration & Production International and Exploration & Production USA. Global Strategy & Business development is divided and merged into the Safety, Security and Sustainability. The operating segment Technology, Innovation and Projects, Drilling & Procurement. The new organisational corporate structure has not resulted in reportable segments. The Exploration & Production business areas are responsible for the discovery and appraisal of new development of the oil and gas portfolios within their respective geographical areas: EPN on the in USA and EPI worldwide outside of EPN and EPUSA. The PDP is responsible for field development, well deliveries and procurement in Equinor. TDI brings together research, technology development, specialist advisory services, digitalisation, IT, improvement, innovation, ventures and future business to one technology powerhouse. The MMP business area is responsible for marketing and trading of oil and gas commodities products, natural gas and liquified natural gas), electricity and emission rights, as well as transportation, manufacturing of the above-mentioned commodities, operations of refineries, terminals and processing - and carbon solutions including carbon capture and storage which was previously the responsibility of the REN business The REN business area is responsible for wind parks and other renewable energy solutions. The reporting segments Exploration & Production Norway (E&P Norway), Exploration & Production Exploration & Production USA (E&P USA), Marketing, Midstream & Processing (MMP) and Renewables business areas EPN, EPI, EPUSA, MMP and REN respectively. The operating segments, PDP, TDI and corporate staffs and functions are aggregated into the reporting segment “Other” due to the immateriality of these operating within the operating segments PDP and TDI are allocated to the E&P Norway, E&P International, E&P USA, MMP and REN reporting segments. The changes do not have a material effect on comparable figures. As from the first quarter of 2021, Equinor changed its reporting as REN became a separate reporting activities in REN were reported in the segment “Other”. The new reporting structure has been applied figures reclassified. The change has its basis in the increased strategic importance of the renewable business information is regarded useful for the readers of the financial statements. Inter-segment sales and related unrealised profits, mainly from the sale of crude oil and products, column below. Inter-segment revenues are based upon estimated market prices. Segment data for the years ended 31 December 2021, 2020 and 2019 are presented profit is net operating income/(loss). allocated to the segments. The measurement basis for segments is IFRS as applied by the group with the exception of IFRS Additions to property, plant and equipment (PP&E), intangibles and equity accounted investments. All IFRS 16 leases are presented within the Other segment. The lease costs for the period are allocated to the different segments with a corresponding credit in the Other segment. Lease costs allocated to licence partners are recognised Other segment. Additions to PP&E, intangible assets and equity accounted investments in period’s allocated lease costs related to activity being capitalised with a corresponding negative addition in the line item Additions to property, plant and equipment (PP&E), intangibles and equity accounted investments excludes movements related to changes in asset retirement obligations. Full year 2021 E&P Norway E&P International E&P USA MMP REN Other Eliminations Total (in USD million) Revenues third party, other revenue and other income 269 1,113 377 87,025 1,394 485 0 90,665 Revenues inter-segment 38,972 4,230 3,771 321 0 5 (47,300) 0 Net income/(loss) from equity accounted investments 0 214 0 22 16 7 0 259 Total revenues and other income 39,241 5,558 4,149 87,368 1,411 497 (47,300) 90,924 Purchases [net of inventory variation] 0 (58) 0 (80,873) 0 (1) 45,773 (35,160) Operating, selling, general and administrative expenses (3,729) (1,466) (1,076) (4,276) (163) 264 1,066 (9,378) Depreciation, amortisation and net impairment losses (4,678) (3,257) (1,733) (1,079) (3) (970) 0 (11,719) Exploration expenses (363) (451) (190) 0 0 0 0 (1,004) Total operating expenses (8,770) (5,232) (2,999) (86,227) (166) (707) 46,839 (57,261) Net operating income/(loss) 30,471 326 1,150 1,141 1,245 (210) (461) 33,663 Additions to PP&E, intangibles and equity accounted investments 5,101 1,828 690 221 455 212 0 8,506 Balance sheet information Equity accounted investments 3 1,417 0 113 1,108 45 0 2,686 Non-current segment assets 35,301 15,358 11,406 3,019 154 3,288 0 68,527 Non-current assets not allocated to segments 13,406 Total non-current assets 84,618 Full year 2020 E&P Norway E&P International E&P USA MMP REN 1) Other 1) Eliminations Total (in USD million) Revenues third party, other revenue and other income 91 451 368 44,605 18 232 0 45,765 Revenues inter-segment 11,804 3,183 2,247 309 0 4 (17,547) 0 Net income/(loss) from equity accounted investments 0 (146) 0 31 163 5 0 53 Total revenues and other income 11,895 3,489 2,615 44,945 181 241 (17,547) 45,818 Purchases [net of inventory variation] 0 (72) 0 (38,072) 0 1 17,157 (20,986) Operating, selling, general and administrative expenses (2,829) (1,439) (1,313) (5,060) (215) 634 685 (9,537) Depreciation, amortisation and net impairment losses (5,546) (3,471) (3,824) (1,453) (1) (939) 0 (15,235) Exploration expenses (423) (2,071) (990) 0 0 1 0 (3,483) Total operating expenses (8,798) (7,054) (6,127) (44,586) (216) (304) 17,842 (49,241) Net operating income/(loss) 3,097 (3,565) (3,512) 359 (35) (63) 296 (3,423) Additions to PP&E, intangibles and equity accounted investments 4,851 2,609 1,068 190 31 1,013 0 9,762 Balance sheet information Equity accounted investments 3 1,125 0 92 1,017 25 0 2,262 Non-current segment assets 2) 37,733 17,835 12,586 4,368 3 4,132 0 76,657 Non-current assets not allocated to segments 13,704 Total non-current assets 92,623 1) Reclassified. 2) Restated. For more information, see note 21 Full year 2019 E&P Norway E&P International E&P USA MMP REN 1) Other 1) Eliminations Total (in USD million) Revenues third party, other revenue and other income 1,048 1,685 441 60,491 258 269 0 64,194 Revenues inter-segment 17,769 4,376 3,792 439 0 4 (26,379) 0 Net income/(loss) from equity accounted investments 15 24 6 25 95 (1) 0 164 Total revenues and other income 18,832 6,085 4,239 60,955 353 271 (26,379) 64,357 Purchases [net of inventory variation] (1) (34) 0 (54,454) 0 (1) 24,958 (29,532) Operating, selling, general and administrative expenses (3,284) (1,684) (1,668) (4,897) (192) 465 793 (10,469) Depreciation, amortisation and net impairment losses (5,439) (2,228) (4,133) (600) (1) (803) 0 (13,204) Exploration expenses (478) (668) (709) 0 0 0 0 (1,854) Total operating expenses (9,201) (4,614) (6,510) (59,951) (193) (339) 25,750 (55,058) Net operating income/(loss) 9,631 1,471 (2,271) 1,004 160 (68) (629) 9,299 Additions to PP&E, intangibles and equity accounted investments 7,316 2,851 3,004 788 175 648 0 14,782 Balance sheet information Equity accounted investments 3 321 0 90 1,003 25 0 1,442 Non-current segment assets 2) 34,938 21,161 16,929 5,248 187 4,026 0 82,489 Non-current assets not allocated to segments 11,152 Total non-current assets 95,083 1) Reclassified. 2) Restated. For more information, see note 21 Provisions Non-current assets by country At 31 December (in USD million) 2021 2020 2) Norway 40,564 44,311 USA 12,323 13,383 Brazil 8,751 8,359 UK 2,096 4,491 Azerbaijan 1,654 1,708 Canada 1,403 1,584 Russia 1,235 973 Angola 948 883 Algeria 708 808 Denmark 536 953 Other 996 1,465 Total non-current assets 1) 71,213 78,919 See note 5 Acquisitions and disposals for information on transactions that affect the different segments. See note 11 Property, different segments. See note 12 Intangible assets for information on impairment losses and impairment reversals See note 24 Other commitments, contingent liabilities and contingent assets for information on Revenues from contracts with customers by geographical areas Equinor has business operations in around 30 When attributing the line item Revenues third party, other revenue and other income to the country of the legal entity executing the sale for 2021, Norway constitutes 81 % and USA constitutes 13 %. For 2020 the revenues to Norway and USA constituted 80 % and 14 % respectively, and for 2019 75 % and 18 % respectively. Revenues from contracts with customers and (in USD million) 2021 2020 2019 Crude oil 38,307 24,509 33,505 Natural gas 28,050 7,213 11,281 24,900 5,839 9,366 1,783 1,010 1,359 1,368 363 556 Refined products 11,473 6,534 10,652 Natural gas liquids 8,490 5,069 5,807 Transportation 921 1,083 967 Other sales 1,006 681 445 Total revenues from contracts with customers 88,247 45,088 62,657 Taxes paid in-kind 345 93 344 Physically settled commodity derivatives (1,075) 209 (1,086) Gain/(loss) on commodity derivatives 951 108 732 Other revenues 276 256 265 Total other revenues 497 665 254 Revenues 88,744 45,753 62,911

Acquisitions and disposals

Acquisitions and disposals	12 Months Ended
	Dec. 31, 2021
Disclosure Of Business Combination And Discontinued Operatons [Abstract]
Disclosure Of Business Combination And Divestment [text block]	5 Acquisitions and disposals 2021 Disposals 10% of Dogger Bank Farm C On 10 February 2022, Equinor closed an agreement with Eni to sell a 10 % interest in the Dogger Bank Wind Farm C project in the UK for a consideration of GBP 68 92 interest in Dogger Bank C from project partner SSE Renewables on the same terms. The new is SSE Renewables ( 40 %), Equinor ( 40 %) and Eni ( 20 %). The asset was classified as held for sale at 31 December 2021. The carrying amount of the interests to be disposed of is immaterial and is reported in the REN REN segment in the first quarter 2022. Equinor Refining Denmark A/S On 31 December 2021, Equinor Danmark A/S closed the transaction with the Klesch Group to sell 100 % of the shares in Equinor Refining Denmark A/S (ERD). Klesch paid USD 48 the Kalundborg refinery and associated terminals and infrastructure. Following an impairment earlier an immaterial loss. Prior to transaction closing, Equinor received USD 335 in capital from ERD. Following the disposal, a gain of USD 167 statement of income in the line item Other income and has been reflected in the MMP segment. Terra Nova On 8 September 2021, Equinor closed the transaction with Cenovus and Murphy to 100 % of its interest, which includes a release of any future obligations and liabilities, in the Terra Nova asset in offshore Canada. The transaction is accounted for in the E&P International segment. The consideration paid, the net carrying amount and the impact to the Consolidated immaterial. Bakken onshore unconventional field On 26 April 2021, Equinor closed the transaction to divest its interests in the Bakken Montana to Grayson Mill Energy, backed by EnCap Investments for an estimated total consideration of USD 819 interim period settlement, for which payment has been received in the first half of 2021. Post-closing settlement ongoing, and the consideration will be final in early 2022. The asset was impaired in the first quarter three quarters of 2021 insignificant losses were recorded and are presented in the line item Operating statement of income in the E&P USA segment. 10% of Dogger Bank Farm A and B On 26 February 2021, Equinor closed the transaction with Eni to sell a 10 % equity interest in the Dogger Bank Wind Farm A and B assets in the UK for a total consideration of GBP 206.4 285 202.8 280 million). After closing, the new overall shareholdings in Dogger Bank A and Dogger Bank B are SSE 40 %), Equinor ( 40 %), and Eni ( 20 %). Equinor will continue to equity account for the remaining investment as the line item Other income in the Consolidated statement of income in the REN segment. Non-operated interest in the Empire Wind and Beacon Wind assets on the US east coast On 29 January 2021, Equinor closed the transaction with BP to sell 50 % of the non-operated interests in the Empire Wind and Beacon Wind assets for a preliminary total consideration after interim period adjustments of USD 1.2 1.1 billion for the divested part, of which USD 500 two companies have established a strategic partnership for further growth within offshore wind in the USA. Equinor remains the operator with a 50 % interest. Equinor consolidated the assets until transaction closing, and thereafter the investments are classified as joint ventures and accounted for using the equity method. The gain is income in the Consolidated statement of income in the REN segment. For further information made to the section Accounting judgement regarding partial divestments and the related policy in note 2 policies. Acquisitions Wento On 5 May 2021, Equinor completed a transaction to acquire 100 % of the shares in Polish onshore renewables developer Wento from the private equity firm Enterprise Investors for a cash consideration of EUR 98 117 addition, Equinor acquired a receivable of USD 3 to the acquired business have been recognised under the acquisition method. In the second quarter an increase of Equinor’s intangible assets of USD 46 59 9 other net assets of USD 21 market obtained in the acquisition. The transaction has been accounted for in the REN segment. Held for sale Equinor Energy Ireland Limited In the fourth quarter of 2021, Equinor entered into an agreement with Vermilion Energy Inc (Vermilion) to sell Equinor’s non-operated equity position in the Corrib gas project in Ireland. The transaction covers a sale of 100 % of the shares in Equinor Energy Ireland Limited (EEIL). EEIL owns 36.5 % of the Corrib field alongside the operator Vermilion ( 20 %) and Nephin Energy ( 43.5 %). Equinor and Vermilion have agreed a consideration of USD 434 production level and gas prices. Closing is expected during 2022. 2020 Acquisition onshore Russia In the fourth quarter of 2020, Equinor closed a transaction with Rosneft to acquire a 49 % interest in the limited liability company LLC KrasGeoNaC (KGN) which holds twelve conventional onshore exploration and production licences in Eastern consideration at closing, including interim period adjustment, was USD 384 recognised a contingent consideration of USD 145 acquisition of USD 529 the E&P International segment. As part of this agreement, Equinor extinguished its exploration commitments offshore in the Sea of Okhotsk and as no outstanding obligations in that area. The previous commitment in the Sea of Okhotsk has been charged estimated fair value of USD 166 the E&P International segment. Divestment of remaining shares in Lundin In the second quarter of 2020, Equinor closed the divestment of its remaining ( 4.9 %) financial shareholding in Lundin Energy AB (formerly Lundin Petroleum AB). The consideration was SEK 3.3 0.3 income in the second quarter was a loss of USD 0.1 items. Investment in interest onshore Argentina In the first quarter of 2020, Equinor closed a transaction to acquire a 50 % ownership share in SPM Argentina S.A (SPM) from Schlumberger Production Management Holding Argentina B.V. Shell acquired the remaining 50 % ownership share of SPM. SPM holds a 49 % interest in the Bandurria Sur onshore block in Argentina, and the block is in the consideration including final adjustments is USD 187 Bandurria Sur by 5.5 % to 30 % for a final consideration of USD 44 using the equity method and reported in the E&P International segment.

Financial risk and capital mana

Financial risk and capital management	12 Months Ended
	Dec. 31, 2021
Financial risk and capital management [Abstract]
Disclosure of financial risk and capital management [text block]	6 Financial risk and capital management General information relevant to financial risks Equinor's business activities naturally expose Equinor to financial risk. Equinor’s approach and managing risk in activities using a holistic risk approach, by considering relevant correlations at portfolio level important market risks and the natural hedges inherent in Equinor’s portfolio. This risk management The corporate risk committee, which is headed by the chief financial officer, is responsible Equinor’s Enterprise Risk Management and proposing appropriate measures to adjust risk at the corporate level. This includes assessing Equinor’s Financial risks Equinor’s activities expose Equinor to market risk (including commodity price risk, currency risk), liquidity risk and credit risk. Market risk Equinor operates in the worldwide crude oil, refined products, natural gas, and electricity including fluctuations in hydrocarbon prices, foreign currency rates, interest rates, and electricity and costs of operating, investing and financing. These risks are managed primarily on a short-term basis highest risk-adjusted returns for Equinor within the given mandate. Long-term exposures are managed short-term exposures are managed according to trading strategies and mandates. Mandates in the oil, refined products, natural gas and electricity are relatively small compared to the total market For more information on sensitivity analysis of market risk see note 26 Financial instruments: fair analysis of market risk. Commodity price risk Equinor’s most important long-term commodity risk (oil and natural gas) is related be exposed to both upside and downside price movements. compound the portfolio commodity price risk. To manage short-term commodity risk, Equinor enters into commodity-based derivative contracts, including futures, options, over-the-counter (OTC) forward contracts, market swaps crude oil, petroleum products, natural gas, indices with a combination of gas price markers. The term of crude oil and refined oil products derivatives are usually less than one year, and they are traded mainly on the Inter Continental Exchange (ICE) in London, the New York Mercantile Exchange (NYMEX), the OTC Brent market, and crude and refined products swap markets. The term of natural gas, OTC physical forwards and options, NASDAQ OMX Oslo forwards and futures traded on the European Energy NYMEX and ICE. Currency risk Equinor’s cash flows from operating activities deriving from oil and gas sales, in USD, but taxes, dividends to shareholders on the Oslo Børs and a share of our operating NOK. Accordingly, Equinor’s currency management is primarily linked to mitigate currency risk related to payments in NOK. This means that Equinor regularly purchases NOK, primarily spot, but also on a forward basis Interest rate risk Bonds are normally issued at fixed rates in a variety of currencies (among others USD, EUR to floating USD bonds by using interest rate and currency swaps. Equinor manages its interest on risk and reward considerations from an enterprise risk management perspective. This rate exposure may vary from time to time. For more detailed information about Equinor’s debt. Equity price risk Equinor’s captive insurance company holds listed equity securities as part of its portfolio. and non-listed equities mainly for long-term strategic purposes. By holding these assets, Equinor defined as the risk of declining equity prices, which can result in a decline in the carrying balance sheet. The equity price risk in the portfolio held by Equinor’s captive maintaining a moderate risk profile, through geographical diversification and the use of broad Liquidity risk Liquidity risk is the risk that Equinor will not be able to meet obligations of financial liquidity management is to ensure that Equinor has sufficient funds available at all times to cover its financial The main cash outflows include the quarterly dividend payments and Norwegian petroleum tax the cash flow forecasts indicate that the liquid assets will fall below target levels, new long-term Short-term funding needs will normally be covered by the USD 5.0 a revolving credit facility of USD 6.0 19 maturing in 2024 . The facility supports secure access to funding, supported by the best available short-term rating. As at 31 December 2021 the facility Equinor raises debt in all major capital markets (USA, Europe and Asia) for long-term funding purposes. The policy is to have a maturity profile with repayments not exceeding 5% of capital employed in any year for the nearest five years. financial liabilities have a weighted average maturity of approximately ten years . For more information about Equinor’s non-current financial liabilities, see note 19 Finance The table below shows a maturity profile, based on undiscounted contractual cash flows, for Equinor’s At 31 December 2021 2020 (in USD million) Non-derivative financial liabilities Lease liabilities Derivative financial liabilities Non-derivative financial liabilities Lease liabilities Derivative financial liabilities Year 1 18,841 1,183 175 13,388 1,220 1,262 Year 2 and 3 6,684 1,262 211 5,528 1,598 75 Year 4 and 5 6,140 656 318 6,489 772 264 Year 6 to 10 10,636 642 588 12,401 752 269 After 10 years 12,849 158 187 14,614 162 425 Total specified 55,150 3,901 1,479 52,421 4,504 2,294 Credit risk Credit risk is the risk that Equinor’s customers or counterparties will cause Equinor financial loss Credit risk arises from credit exposures with customer accounts receivables as well as from financial investments, instruments and deposits with financial institutions. Prior to entering into transactions with new counterparties, Equinor’s credit policy requires all counterparties to be formally identified and assigned internal credit ratings. The internal credit ratings reflect Equinor’s assessment of the counterparties' credit risk and are based on a quantitative and qualitative analysis of recent financial statements and other relevant business. All counterparties are re- assessed regularly. Equinor uses risk mitigation tools to reduce or control credit risk both on a counterparty and portfolio bank and parental guarantees, prepayments and cash collateral. Equinor has credit exposures for individual counterparties. Equinor monitors the portfolio on on a daily basis. The total credit exposure of Equinor is geographically diversified among a number of counterparties within the oil energy sector, investment grade counterparties. The following table contains the carrying amount of Equinor’s financial receivables and derivative Equinor’s assessment of the counterparty's credit risk. Trade and other receivables include 1 % overdue receivables for 30 days and more. The overdue receivables are mainly joint venture receivables pending the settlement of disputed from Equinor’s working interest partners within the Exploration & Production USA recognized for expected credit losses of trade and other receivables using the expected credit loss model. Only non-exchange traded instruments are included in derivative financial instruments. (in USD million) Non-current financial receivables Trade and other receivables Non-current derivative financial instruments Current derivative financial instruments At 31 December 2021 Investment grade, rated A or above 452 3,637 1,103 2,902 Other investment grade 18 8,930 0 1,524 Non-investment grade or not rated 238 4,624 162 705 Total financial assets 708 17,191 1,265 5,131 At 31 December 2020 Investment grade, rated A or above 211 1,954 1,850 465 Other investment grade 24 2,288 478 287 Non-investment grade or not rated 262 3,176 148 134 Total financial assets 497 7,418 2,476 886 For more information about Trade and other receivables, see note 16 Trade and other receivables. At 31 December 2021, USD 2.271 December 2020, USD 1.704 related to positive fair values on interest rate swaps, cross currency swaps and foreign exchange accordance with the master agreements with the different counterparties when the positive fair values for agreements are above an agreed threshold. Under the terms of various master netting agreements for derivative financial instruments as of 31 December 2021, USD 24.536 billion have been offset and USD 0.500 USD 3.738 0.387 financial instrument liabilities, reduce the credit exposure in the derivative financial instruments will offset in a potential default situation for the counterparty. For trade and other receivables subject to similar master netting agreements USD 4.445 1.684 2020. Capital management The main objectives of Equinor's capital management policy are to maintain a strong overall financial financial flexibility. Equinor’s primary focus is on maintaining its credit rating in the A category on a stand alone basis (excluding uplifts for Norwegian Government ownership). Equinor’s current long-term ratings are AA- with and Aa2 with a stable outlook (including two notch uplift) from S&P on a day to day basis, a key ratio utilized by Equinor is the non-GAAP metric of “Net interest-bearing employed adjusted (CE)”. At 31 December (in USD million) 2021 2020 Net interest-bearing debt adjusted, including lease 3,236 20,121 Net interest-bearing debt adjusted (ND2) (326) 15,716 Capital employed adjusted, including lease liabilities 42,259 54,012 Capital employed adjusted (CE2) 38,697 49,608 Net debt to capital employed adjusted, including 7.7% 37.3% Net debt to capital employed adjusted (ND2/CE2) (0.8%) 31.7% ND1 is defined as Equinor's interest bearing financial liabilities less cash and cash equivalents and adjusted for collateral deposits and balances held by Equinor's captive insurance company (amounting to USD 2.369 627 ND2 is defined as ND1 adjusted for lease liabilities (amounting to USD 3.562 4.405 respectively). CE2 is defined as Equinor's total equity (including non-controlling interests) and ND2.

Remuneration

Remuneration	12 Months Ended
	Dec. 31, 2021
Renumeration [abstract]
Disclosure of renumeration explanatory [text block]	7 Remuneration Full year (in USD million, except average number of employees) 2021 2020 2019 Salaries 1) 2,962 2,625 2,766 Pension costs 2) 488 432 446 Payroll tax 414 368 413 Other compensations and social costs 288 283 330 Total payroll costs 4,152 3,707 3,955 Average number of employees 3) 21,400 21,700 21,400 Salaries include bonuses, severance packages and expatriate costs in addition to base pay. 2) 3) 3 % for 2021, 2 % for 2020 and 4 % for 2019. Total payroll expenses are accumulated in cost-pools and partly charged to partners of Equinor operated licences on an hours incurred basis. Full year (in USD thousand) 1) 2021 2020 2019 Current employee benefits 12,229 9,012 10,958 Post-employment benefits 420 589 661 Other non-current benefits 17 14 18 Share-based payment benefits 83 125 147 Total benefits 12,749 9,740 11,782 1) All figures in the table are presented on accrual basis. At 31 December 2021, 2020 and 2019 there are no Share-based compensation Equinor's share saving plan provides employees with the opportunity to purchase Equinor shares through monthly and a contribution by Equinor. If the shares are kept for two full calendar years of continued employment following the year of purchase, the employees will be allocated one bonus share for each one they have purchased. Estimated compensation expense including the contribution by Equinor for purchased shares, amounts granted and related social security tax was USD 79 74 73 programmes, respectively. For the 2022 programme (granted in 2021), the estimated compensation expense is USD 85 December 2021 the amount of compensation cost yet to be expensed throughout the vesting period is USD 174 See note 18 Shareholders’ equity and dividends for more information about share-based compensation.

Other expenses

Other expenses	12 Months Ended
	Dec. 31, 2021
Other Expense [Abstract]
Disclosure of Other expenses [text block]	8 Other expenses Auditor's remuneration Full year (in USD million, excluding VAT) 2021 2020 2019 Audit fee Ernst & Young (principal accountant from 2019) 14.4 10.7 4.7 Audit fee KPMG (principal accountant 2018) - 2.8 Audit related fee Ernst & Young (principal accountant from 2019) 1.1 1.0 0.5 Audit related fee KPMG (principal accountant 2018) - 1.2 Tax fee Ernst & Young - - 0.2 Tax fee KPMG (principal accountant 2018) - - Other service fee Ernst & Young (principal accountant from 2019) - - 0.9 Other service fee KPMG (principal accountant 2018) - - Total remuneration 15.5 11.7 10.3 In addition to the figures in the table above, the audit fees and audit related fees 0.5 0.5 0.5 Research and development expenditures Equinor has Research and development (R&D) activities within exploration, subsurface, drilling and renewables. Our R&D contributes to maximizing and developing long-term value from Equinor’s R&D expenditures were USD 291 254 300 expenditures are partly financed by partners of Equinor operated licences. Equinor's share the Total operating expenses in the Consolidated statement of income.

Financial items

Financial items	12 Months Ended
	Dec. 31, 2021
Finance Income Expense [Abstract]
Disclosure of finance income (cost) [text block]	9 Financial items Full year (in USD million) 2021 2020 2019 Foreign currency exchange gains/(losses) derivative 870 (1,288) 132 Other foreign currency exchange gains/(losses) (823) 642 92 Net foreign currency exchange gains/(losses) 47 (646) 224 Dividends received 39 44 75 Interest income financial investments, including 38 108 125 Interest income non-current financial receivables 26 34 21 Interest income other current financial assets and other 48 113 281 Interest income and other financial items 151 298 502 Gains/(losses) financial investments (348) 456 243 Gains/(losses) other derivative financial instruments (708) 448 473 Interest expense bonds and bank loans and net (896) (951) (987) Interest expense lease liabilities (93) (104) (126) Capitalised borrowing costs 334 308 480 Accretion expense asset retirement obligations (453) (412) (456) Interest expense current financial liabilities and (114) (232) (360) Interest and other finance expenses (1,223) (1,392) (1,450) Net financial items (2,080) (836) (7) Equinor's main financial items relate to assets and liabilities categorised in the fair value through profit or loss category. For more information about financial instruments by category see note 26 Financial instruments: fair value measurement and sensitivity analysis of market risk. The line item Interest expense bonds and bank loans and net interest on related derivatives 0.990 billion, USD 1.031 0.861 category. It also includes net interest on related derivatives from the fair value through profit or loss category, amounting to a net interest income of USD 0.094 0.079 0.129 billion for 2020 and 2019, respectively. The line item Gains/(losses) other derivative financial instruments primarily includes fair value changes from the fair profit or loss category on derivatives related to interest rate risk. For 2021 it is a loss of USD 724 USD 432 457 Foreign currency exchange gains/(losses) derivative financial instruments include fair value changes of currency liquidity and currency risk. The line item Other foreign currency exchange gains/(losses) includes of USD 702 796 74 2020 and 2019, respectively.

Income taxes

Income taxes	12 Months Ended
	Dec. 31, 2021
Income tax [abstract]
Disclosure of income tax [text block]	10 Income taxes Significant components of income tax expense Full year (in USD million) 2021 2020 2019 Current income tax expense in respect of (21,271) (1,115) (7,892) Prior period adjustments (28) 313 69 Current income tax expense (21,299) (802) (7,822) Origination and reversal of temporary differences (1,778) (648) 410 Recognition of previously unrecognised deferred 126 130 0 Change in tax regulations 4 (12) (6) Prior period adjustments (60) 94 (23) Deferred tax income/(expense) (1,708) (435) 381 Income tax (23,007) (1,237) (7,441) As a measure to maintain activity in the oil and gas related industry during the Covid-19 pandemic, 19 June 2020 enacted temporary targeted changes to Norway’s petroleum tax system for investments incurred in for new projects with Plans for development and operations (PDOs) or Plans for installation and Ministry of Oil and Energy by the end of 2022 and approved prior to 1 January 2024. The changes are effective from 1 January 2020 and provide companies with a direct tax deduction in the special petroleum tax ( 56 % tax rate) instead of tax depreciation over six years. In addition, the tax uplift benefit, which has increased from 20.8 % to 24 %, will be recognised over one year instead of four years. Tax depreciation towards the ordinary offshore corporate tax ( 22 % tax rate) will continue with a six-year depreciation profile. Reconciliation of statutory tax rate to effective Full year (in USD million) 2021 2020 2019 Income/(loss) before tax 31,583 (4,259) 9,292 Calculated income tax at statutory rate 1) (7,053) 1,445 (2,284) Calculated Norwegian Petroleum tax 2) (17,619) (2,126) (5,499) Tax effect uplift 3) 914 1,006 632 Tax effect of permanent differences regarding divestments 90 (9) 380 Tax effect of permanent differences caused by functional currency different from tax currency 150 (198) 8 Tax effect of other permanent differences 228 450 395 Recognition of previously unrecognised deferred tax 126 130 0 Change in unrecognised deferred tax assets 619 (1,685) (974) Change in tax regulations 4 (12) (6) Prior period adjustments (88) 408 47 Other items including foreign currency effects (378) (647) (139) Income tax (23,007) (1,237) (7,441) Effective tax rate 72.8% -29.0% 80.1% The weighted average of statutory tax rates was 22.3 % in 2021, 33.9 % in 2020 and 24.6 % in 2019. The rates are influenced by earnings composition between tax regimes with lower statutory tax rates and tax regimes with 2) 56 %. 3) 56 % on income from the Norwegian continental shelf, an additional tax-free allowance, uplift, is granted on the basis of the original capitalised cost of offshore production installations. Normally, a 5.2 % uplift may be deducted from taxable income for a period of four years starting in the year in which the and 2021 temporary rules allow direct deduction of the whole uplift at a rate of 24 % in the year the capital expenditure is incurred. For investments made in 2019 the uplift is calculated at a rate of 5.2 % per year, while the rate is 5.3 % per year for investments made in 2018 and 7.5 % per year for investments under the transitional rules from 2013. Unused uplift may indefinitely. At year-end 2021 and 2020, unrecognised uplift credits amounted to USD 272 836 respectively. Deferred tax assets and liabilities comprise (in USD million) Tax losses carried forward Property, plant and equipment and intangible assets 1) Asset retirement obligations 1) Lease liabilities Pensions Derivatives Other Total Deferred tax at 31 December 2021 Deferred tax assets 5,162 719 11,256 1,506 804 21 2,015 21,484 Deferred tax liabilities 0 (27,136) 0 0 (21) (1,453) (530) (29,140) Net asset/(liability) at 31 December 2021 5,162 (26,417) 11,256 1,506 783 (1,432) 1,485 (7,655) Deferred tax at 31 December 2020 Deferred tax assets 4,676 826 12,967 1,869 787 30 1,811 22,966 Deferred tax liabilities 0 (28,290) 0 (4) (11) (236) (676) (29,217) Net asset/(liability) at 31 December 2020 4,676 (27,464) 12,967 1,865 777 (206) 1,135 (6,250) Restated 2020 figures due to a policy change affecting ARO calculation, see note 2 Significant accounting policies. The deferred tax liability in Property, plant and equipment and intangible assets has increased by USD 1.762 deferred tax asset in Asset retirement obligations has increased by USD 1.762 Changes in net deferred tax liability during (in USD million) 2021 2020 2019 Net deferred tax liability at 1 January 6,250 5,530 5,367 Charged/(credited) to the Consolidated statement of 1,708 435 (381) Charged/(credited) to Other comprehensive income 35 (19) 98 Foreign currency translation effects and other effects (337) 304 446 Net deferred tax liability at 31 December 7,655 6,250 5,530 Deferred tax assets and liabilities are offset to the extent that the deferred taxes relate to the same fiscal legally enforceable right to offset current tax assets against current tax liabilities. After netting deferred tax assets and fiscal entity and reclassification to Held for Sale, deferred taxes are presented on the balance sheet At 31 December (in USD million) 2021 2020 Deferred tax assets 6,259 4,974 Deferred tax liabilities 14,037 11,224 Deferred tax assets reported in Assets classified as 122 0 Deferred tax assets are recognised based on the expectation that sufficient taxable income will be available taxable temporary differences or future taxable income. At year-end 2021 and 2020 the deferred tax assets of USD 6.381 USD 4.974 4.636 2.328 preceding period. The losses will be utilised through reversal of taxable temporary differences and other taxable production of oil and gas. It is considered probable based on business forecasts and/or will be available. Unrecognised deferred tax assets At 31 December 2021 2020 (in USD million) Basis Tax Basis Tax Deductible temporary differences 2,900 1,203 2,866 1,204 Unused tax credits 0 264 0 212 Tax losses carried forward 20,552 5,047 23,434 5,677 Total unrecognised deferred tax assets 23,452 6,514 26,300 7,093 Approximately 22 % of the unrecognised carry forward tax losses can be carried forward indefinitely. The majority of the remaining part of the unrecognised tax losses expire after 2032 . The unrecognised tax credits expire from 2030, while the unrecognised deductible temporary differences do not expire under the current tax legislation. Deferred tax assets have not been recognised these items because currently there is insufficient evidence to support that future taxable profits will be available to secure of the benefits. At year-end 2021, unrecognised deferred tax assets in the USA and Angola represents USD 4.206 0.749 respectively, of the total unrecognised deferred tax assets of USD 6.514 4.649 the USA and USD 0.740 7.093 assets originate from several different tax jurisdictions.

Property, plant and equipment

Property, plant and equipment	12 Months Ended
	Dec. 31, 2021
Property, plant and equipment [abstract]
Disclosure of property, plant and equipment [text block]	11 Property, (in USD million) Machinery, equipment and transportation equipment Production plants and oil and gas assets Refining and manufacturing plants Buildings and land Assets under development Right of use assets 4) Total Cost at 31 December 2020 as reported 2,806 180,355 9,238 929 13,053 6,370 212,751 Impact of policy change 5) - 2,726 - - 110 - 2,836 Cost at 31 December 2020 as restated 2,806 183,082 9,238 929 13,163 6,370 215,587 Additions through business combinations 0 2 0 0 1 0 4 Additions and transfers 39 7,311 95 27 (396) 148 7,225 Disposals at cost (1,496) (1,975) (70) (353) (25) (501) (4,420) Assets reclassified to held for sale 0 (1,010) (563) 0 0 (91) (1,664) Foreign currency translation effects (13) (4,052) (220) (6) (130) (77) (4,497) Cost at 31 December 2021 1,335 183,358 8,481 596 12,614 5,850 212,234 Accumulated depreciation and impairment losses at 31 December 2020 (2,596) (132,427) (8,005) (524) (1,275) (2,251) (147,079) Depreciation (68) (9,136) (232) (42) 0 (930) (10,408) Impairment losses (42) (2,092) (401) (21) (390) (17) (2,962) Reversal of impairment losses 0 1,675 0 0 0 2 1,677 Transfers 61 (1,319) 0 (61) 1,319 (11) (11) Accumulated depreciation and impairment on disposed assets 1,448 1,785 59 326 21 480 4,118 Accumulated depreciation and impairment assets classified as held for sale 0 825 461 0 0 82 1,367 Foreign currency translation effects 9 2,926 192 2 (18) 27 3,138 Accumulated depreciation and impairment losses at 31 December 2021 (1,188) (137,763) (7,926) (320) (344) (2,619) (150,159) Carrying amount at 31 December 2021 147 45,595 555 276 12,270 3,231 62,075 Estimated useful lives (years) UoP 1) 2) 3) (in USD million) Machinery, equipment and transportation equipment Production plants and oil and gas assets Refining and manufacturing plants Buildings and land Assets under development Right of use assets 4) Total Cost at 31 December 2019 as reported 2,818 179,063 8,920 909 10,371 5,339 207,422 Impact of policy change 5) - 1,762 - - 37 - 1,799 Cost at 31 December 2019 as restated 2,818 180,825 8,920 909 10,408 5,339 209,221 Additions and transfers 68 7,782 110 27 2,478 968 11,433 Disposals at cost (28) (243) (7) 0 (5) (13) (295) Assets reclassified to held for sale (66) (9,095) 0 (15) (159) 0 (9,335) Foreign currency translation effects 13 3,812 214 7 441 75 4,563 Cost at 31 December 2020 2,806 183,082 9,238 929 13,163 6,370 215,587 Accumulated depreciation and impairment losses at 31 December 2019 (2,395) (125,327) (7,051) (475) (892) (1,329) (137,469) Depreciation (102) (8,240) (248) (23) 0 (874) (9,488) Impairment losses (201) (4,667) (516) (36) (445) (25) (5,889) Reversal of impairment losses 0 218 0 0 0 0 218 Transfers 18 (68) (1) 0 41 0 (10) Accumulated depreciation and impairment on disposed assets 27 231 7 0 1 11 278 Accumulated depreciation and impairment assets classified as held for sale 65 8,373 0 12 75 0 8,525 Foreign currency translation effects (9) (2,947) (196) (3) (56) (35) (3,244) Accumulated depreciation and impairment losses at 31 December 2020 (2,596) (132,427) (8,005) (524) (1,275) (2,251) (147,079) Carrying amount at 31 December 2020 209 50,654 1,232 405 11,888 4,119 68,508 Estimated useful lives (years) UoP 1) 2) 3) Depreciation according to unit of production method (UoP), see note 2 Significant accounting policies . 2) . Buildings include leasehold improvements. 3) 4) 5) lines are also impacted by the policy change. The carrying amount of assets transferred to Property plant and equipment from Intangible assets in 2021 and 2020 amounted to USD 1.730 0.089 For assets reclassified to held for sale, see note 5 Acquisitions and disposals. Net impairments/(reversal) of impairments Full year Property, plant and equipment 3) (in USD million) 2021 2020 2019 2021 2020 2019 2021 2020 2019 Producing and development assets 1) 1,285 5,671 3,230 (2) 680 608 1,283 6,351 3,838 Goodwill 1) 1 42 164 1 42 164 Other intangible assets 1) 0 8 41 0 8 41 Acquisition costs related to oil and gas prospects 2) 154 657 49 154 657 49 Total net impairment loss/(reversal) recognised 1,285 5,671 3,230 154 1,386 863 1,439 7,057 4,093 Producing and development assets, refining and manufacturing plants, goodwill and other intangible assets are impairment assessment under IAS 36. The total net impairment losses recognised under IAS 36 in 2021 1.285 billion, compared to 2020 when the net impairment amounted to USD 6.401 and gas prospects (intangible assets). 2) 6). 3) . For impairment purposes, the asset's carrying amount is compared to its recoverable amount. The recoverable fair value less cost of disposal (FVLCOD) and estimated value in use (VIU). The base discount rate for VIU calculations is 5.0 % real after tax. The discount rate is derived from Equinor's weighted average cost of capital. For projects, mainly within the REN segment, in periods with fixed low risk income a lower A derived pre-tax discount is in the range of 18 - 32 % for E&P Norway, 5 - 9 % for E&P International, 6 - 7 % for E&P USA and 7 % for MMP depending on asset specific characteristics, such as specific tax treatments, cash flow profiles and economic Significant accounting policies to the Consolidated financial statements for further information regarding impairment on property, plant and equipment. The table below describes, per area, the Producing and development assets being impaired/(reversed) and the valuation method used to determine the recoverable amount; the net impairment/(reversal), and the carrying amount after impairment. At 31 December 2021 At 31 December 2020 (in USD million) Valuation method Carrying amount after impairment Net impairment loss/ (reversal) Carrying amount after impairment Net impairment loss/ (reversal) Exploration & Production Norway VIU 5,379 (1,102) 7,042 1,219 Exploration & Production USA - onshore VIU 1,979 8 4,676 (19) FVLCOD 0 40 1,122 2,331 Exploration & Production USA - offshore Gulf of Mexico VIU 798 18 2,808 305 North America - offshore other areas VIU 0 0 53 146 FVLCOD 0 (22) 0 0 Europe and Asia VIU 1,566 1,609 3,687 1,280 Marketing, Midstream & Processing VIU 632 486 1,297 824 FVLCOD 236 230 668 228 Right of use assets/Other VIU 16 (2) 265 36 FVLCOD 4 17 0 0 Total 10,610 1,282 21,619 6,351 Exploration & Production Norway In 2021, the impairment reversals were USD 1.102 In 2020, the impairments were USD 1.219 and increased cost estimates added to the impairment losses. Exploration & Production USA - onshore In 2021, the net impairment was USD 48 2 impairments were USD 108 20 revision and sale of an asset. The reversal of USD 60 22 caused by upward reserve revision. In 2020, the net impairment was USD 2.313 0.680 losses of USD 2.547 0.743 assumptions and a change to fair value less cost of disposal valuation in relation to held for reversals of USD 0.234 Exploration & Production USA - offshore Gulf of Mexico In 2021, the impairment was USD 18 In 2020, the impairments were USD 305 Exploration & Production International – North America offshore other areas In 2021, the impairment reversal was USD 22 In 2020, the impairment was USD 146 Exploration & Production International – Europe and Asia In 2021, the net impairment was USD 1.609 1.786 revisions. The reversal of USD 0.177 In 2020, the impairments were USD 1.280 Marketing, Midstream & Processing In 2021, the impairment losses were USD 716 2 fair value less cost of disposal valuation in connection with a held for sale classification. In 2020, the impairment losses were USD 1.052 Reduced volume-estimates from processing added to the impairment loss. Accounting assumptions Management’s future commodity price assumptions and currency assumptions are used for value in use impairment testing. same assumptions are also used for evaluating investment opportunities, together with robustness targets (value creation in lower commodity price scenarios). While there are inherent commodity price assumptions as well as currency assumptions reflect management’s best estimate of the development over the life of the Group’s assets based on its view of relevant current circumstances of such circumstances, including energy demand development, energy and climate change policies as well transition, population and economic growth, geopolitical risks, technology and cost development best estimate also takes into consideration a range of external forecasts. Equinor has performed a thorough and broad analysis of the expected development in drivers for exchange rates. Significant uncertainty exists regarding future commodity price development due to the transition economy, future supply actions by OPEC+ and other factors. The management’s analysis of the expected development in drivers for the different commodity markets and exchange rates resulted in changes in the long-term price assumptions with effect from the third quarter of 2021. The following price assumptions have been the basis for the impairment assessments. All commodity prices are on a real 2021 basis, and comparable prices as per the fourth quarter of 2020 2021 are given in brackets. For Brent 65 67 declining to 64 66 60 unchanged compared to year-end 2020, with the exception that the real year has been changed For natural gas in the UK (NBP), we expect some volatility, where the trend is a decrease to 6.4 6.7 USD/mmbtu). From 2030, a flatter price-curve is expected, with the price gradually increasing to 7.7 8.0 USD/mmbtu). Beyond 2040, a declining price trend is foreseen as the energy transition is expected 2050, the price is expected to be at the pre-2035 level of 7.0 7.7 Henry Hub is expected to decrease to 3.2 3.3 3.3 3.8 level that is expected to continue through the 2040s. The electricity prices are expected to increase significantly in the future. Due to the increasing 2 in Germany are by the end of fourth quarter expected to be 157 61 end of the third quarter was 77 58 43 towards 2050. Climate considerations are included in the impairment calculations directly by estimating the CO 2 the expected effect of climate change is also included in the estimated commodity prices where supply and The prices also have effect on the estimated production profiles and economic cut-off of the projects. Furthermore, climate considerations are a part of the investment decisions following Equinor’s strategy The EU ETS price has increased significantly from 56 in the region of 80 65 27.5 thereafter increasing to 100 41 Plan for the period 2021-2030 (Meld. St 13 (2020-2021)) which assumes a gradually increased 2 Norwegian CO 2 2,000 Impairment calculations are based on what is considered to be best estimate. To reflect that carbon will have a cost for all our assets the current best estimate is considered to be EU ETS for countries outside EU where where Equinor has not established specific estimates. The long-term NOK currency exchange rates are expected to be unchanged. The NOK/USD 8.50 , the NOK/EUR at 10.0 1.35 . The Weighted Average Cost of Capital (WACC) rate is 5 %. This rate is basically the interest rate used for upstream activities. For other business areas the discount rate will be determined based on a risk assessment. assets/projects where the revenue is secured by fixed fees or government grants. Sensitivities Commodity prices have historically been volatile. Significant downward adjustments of Equinor’s result in impairment losses on certain producing and development assets in Equinor’s portfolio subject to impairment assessment, while an opposite adjustment could lead to impairment-reversals. If forecasts over the lifetime of the assets were 30 %, considered to represent a reasonably possible change, the impairment amount to be recognised could illustratively be in the region of USD 9 climate changes for possible effect of using the prices in a 1.5 o C compatible Net Zero Emission by 2050 scenario as estimated by the International Energy Agency (IEA) These illustrative impairment sensitivities, both based on a simplified method, however, a price reduction of 30 % or those representing Net Zero Emission scenario is likely to result in changes in business well as other factors used when estimating an asset’s recoverable amount. These associated changes reduce the stand-alone on the price sensitivities. Changes in such input factors would likely include a reduction in the well as offsetting foreign currency effects, both of which have historically occurred following significant changes in commodity prices. The illustrative sensitivities are therefore not considered to represent a best estimate of an expected impairment estimated impact on revenues or operating above in the accounting assumptions section and the decline in commodity prices, the impairment impact recognised lower. A significant and prolonged reduction in oil and gas prices would also result in mitigating actions by Equinor and its licence partners, as a reduction of oil and gas prices would impact drilling plans and production profiles for Quantifying such impacts is considered impracticable, as it requires detailed technical, geological and on hypothetical scenarios and not based on existing business or development plans.

Intangible Assets

Intangible Assets	12 Months Ended
	Dec. 31, 2021
Disclosure of intangible assets [abstract]
Disclosure of intangible assets [text block]	12 Intangible assets (in USD million) Exploration expenses Acquisition costs - oil and gas prospects Goodwill Other Total Cost at 31 December 2020 2,261 3,932 1,481 831 8,505 Additions through business combinations 0 0 61 55 116 Additions 191 36 0 35 262 Disposals at cost (22) 1 (3) (29) (53) Transfers (432) (1,137) 0 (161) (1,730) Expensed exploration expenditures previously capitalised (19) (152) 0 0 (171) Impairment of goodwill 0 0 (1) 0 (1) Foreign currency translation effects (21) (10) (70) (10) (111) Cost at 31 December 2021 1,958 2,670 1,467 722 6,816 Accumulated depreciation and impairment losses (356) (356) Amortisation and impairments for the year (24) (24) Amortisation and impairment losses disposed intangible 13 13 Foreign currency translation effects 3 3 Accumulated depreciation and impairment losses (364) (364) Carrying amount at 31 December 2021 1,958 2,670 1,467 358 6,452 (in USD million) Exploration expenses Acquisition costs - oil and gas prospects Goodwill Other Total Cost at 31 December 2019 3,014 5,599 1,458 962 11,033 Additions 401 67 0 24 492 Disposals at cost (7) 0 0 0 (8) Transfers (16) (73) 0 0 (89) Assets reclassified to held for sale 0 (339) 0 (160) (499) Expensed exploration expenditures previously capitalised (1,169) (1,337) 0 0 (2,506) Impairment of goodwill 0 0 (42) 0 (42) Foreign currency translation effects 38 16 64 6 123 Cost at 31 December 2020 2,261 3,932 1,481 831 8,505 Accumulated depreciation and impairment losses (295) (295) Amortisation and impairments for the year (35) (35) Accumulated depreciation and impairment assets sale (17) (17) Amortisation and impairment losses disposed intangible (6) (6) Foreign currency translation effects (3) (3) Accumulated depreciation and impairment losses (356) (356) Carrying amount at 31 December 2020 2,261 3,932 1,481 475 8,149 The useful lives of intangible assets are assessed to be either finite or indefinite. Intangible assets with systematically over their estimated economic lives, ranging between 3 - 20 Included in the goodwill of USD 1.467 0.615 Exploration & Production Norway area and USD 0.435 In 2021, Acquisition cost - oil and gas prospects were impacted by net impairment of USD 152 related to exploration activities of USD 154 and Gulf of Mexico. Net reversal of 2 In 2020, Acquisition cost - oil and gas prospects were impacted by net impairment of signature USD 680 exploration activities of USD 657 International. See note 11 Property, In 2020, Equinor decided to impair capitalised well costs of USD 982 Tanzania. Impairment losses and reversals of impairment losses are presented as Exploration expenses and impairment losses on the basis of their nature as exploration assets (intangible assets) and impairment losses and reversal of impairment losses are based on recoverable amount estimates estimates, cost estimates and market conditions. See note 11 Property, plant and equipment for more information on the basis for impairment assessments. The table below shows the aging of capitalised exploration expenditures. (in USD million) 2021 2020 Less than one year 234 604 Between one and five years 692 623 More than five years 1,033 1,033 Total capitalised exploration expenditures 1,958 2,261 The table below shows the components of the exploration Full year (in USD million) 2021 2020 2019 Exploration expenditures 1,027 1,371 1,584 Expensed exploration expenditures previously capitalised 171 2,506 777 Capitalised exploration (194) (394) (507) Exploration expenses 1,004 3,483 1,854

Equity accounted investments

Equity accounted investments	12 Months Ended
	Dec. 31, 2021
Equity accounted investments [Abstract]
Disclosure of equity accounted investments [text block]	13 Equity accounted investments (in USD million) 2021 2020 Net investments at 1 January 2,270 1,487 Net income/(loss) from equity accounted investments 259 53 Acquisitions and increase in capital 475 995 Dividend and other distributions (230) (141) Other comprehensive income/(loss) (58) 21 Divestments, derecognition and decrease in paid in (31) (147) Net investments at 31 December 2,686 2,270 Included in equity accounted investments 2,686 2,262 Other long-term receivable in equity accounted investments 0 8 For the equity accounted investments, voting rights corresponds to ownership. Equity accounted investments consist of several investments, none above USD 0.75 an individual basis.

Financial investments and finan

Financial investments and financial receivables	12 Months Ended
	Dec. 31, 2021
Financial investments and financial receivables [abstract]
Disclosure of financial investments and financial receivables [text block]	14 Financial investments and financial receivables Non-current financial investments At 31 December (in USD million) 2021 2020 Bonds 1,822 1,866 Listed equity securities 778 1,648 Non-listed equity securities 746 569 Financial investments 3,346 4,083 Bonds and equity securities mainly relate to investment portfolios held by Equinor’s captive insurance company non-listed equities held for long-term strategic purposes, mainly accounted for using fair value through profit Included in Listed equity securities are shares in Scatec ASA of USD 360 831 respectively Non-current prepayments and financial receivables At 31 December (in USD million) 2021 2020 Interest bearing financial receivables 707 465 Other interest bearing receivables 276 246 Prepayments and other non-interest bearing receivables 104 150 Prepayments and financial receivables 1,087 861 Interest bearing financial receivables primarily relate to loans to employees and project financing of equity accounted Other interest bearing receivables primarily relate to tax receivables. Current financial investments At 31 December (in USD million) 2021 2020 Time deposits 7,060 4,841 Interest bearing securities 14,186 7,010 Listed equity securities 0 13 Financial investments 21,246 11,865 At 31 December 2021, current financial investments include USD 300 company which mainly are accounted for using fair value through profit or loss. USD 202 For information about financial instruments by category, see note 26 Financial instruments: fair value measurement and sensitivity analysis of market risk .

Inventories

Inventories	12 Months Ended
	Dec. 31, 2021
Inventories [abstract]
Disclosure of inventories [text block]	15 Inventories At 31 December (in USD million) 2021 2020 Crude oil 2,014 2,022 Petroleum products 315 443 Natural gas 642 229 Other 424 390 Inventories 3,395 3,084 Other inventory consists mainly of drilling and well equipment. The write-down of inventories from cost to net realisable value amounted to an expense of USD 77 58 and 2020, respectively.

Trade and other receivables

Trade and other receivables	12 Months Ended
	Dec. 31, 2021
Trade and other receivables [abstract]
Disclosure of trade and other receivables [text block]	16 Trade and other receivables At 31 December (in USD million) 2021 2020 Trade receivables from contracts with customers 13,266 5,729 Other current receivables 3,011 1,275 Joint venture receivables 491 340 Receivables from equity accounted associated companies 423 74 Total financial trade and other receivables 17,191 7,418 Non-financial trade and other receivables 736 814 Trade and other receivables 17,927 8,232 Trade receivables from contracts with customers are shown net of an immaterial provision for expected losses. For more information about the credit quality of Equinor's counterparties, see note 6 Financial risk currency sensitivities, see note 26 Financial instruments: fair value measurement and sensitivity

Cash and cash equivalents

Cash and cash equivalents	12 Months Ended
	Dec. 31, 2021
Cash and cash equivalents [abstract]
Disclosure of cash and cash equivalents [text block]	17 Cash and cash equivalents At 31 December (in USD million) 2021 2020 Cash at bank available 2,673 1,648 Time deposits 1,906 1,132 Money market funds 2,714 492 Interest bearing securities 4,740 2,485 Restricted cash, including margin deposits 2,093 999 Cash and cash equivalents 14,126 6,757 Restricted cash at 31 December 2021 include collateral deposits of USD 2.069 collateral deposits at 31 December 2020 were USD 0.425 exchanges where Equinor is participating. The terms and conditions related to these requirements exchanges.

Shareholders' equity and divide

Shareholders' equity and dividends	12 Months Ended
	Dec. 31, 2021
Shareholders equity and dividends [Abstract]
Shareholders equity and dividends [text block]	18 Shareholders' equity and dividends At 31 December 2021, Equinor’s share capital of NOK 8,144,219,267.50 1,163,987,792 ) comprised 3,257,687,707 nominal value of NOK 2.50 . Share capital at 31 December 2020 was NOK 8,144,219,267.50 1,163,987,792 ) comprised 3,257,687,707 2.50 . Equinor ASA has only one class of shares and all shares have voting rights. The holders and when declared and are entitled to one vote per share at the annual general meeting During 2021 dividend for the third and for the fourth quarter of 2020 and dividend for the Dividend declared but not yet settled, is presented as dividends payable in the Consolidated balance sheet. The Consolidated statement of changes in equity shows declared dividend in the period (retained earnings). Dividend fourth quarter of 2020 and to the first three quarters of 2021. On 8 February 2022, the board of directors proposed to declare a dividend for the fourth quarter 0.20 an extraordinary dividend of USD 0.20 dividend 12 May 2022 on Oslo Børs and for ADR holders on New York Stock Exchange. Record date will be 13 May 2022 and payment date will be 27 May 2022. At 31 December (in USD million) 2021 2020 Dividends declared 2,041 1,833 USD per share or ADS 0.6300 0.5600 Dividends paid 1,797 2,330 USD per share or ADS 0.5600 0.7100 NOK per share 4.8078 6.7583 Share buy-back programme In July 2021 Equinor launched the first tranche of around USD 300 USD 600 initially USD 300 1.0 to USD 99 third party was entered into for up to USD 330 201 670 agreement with the Ministry of Petroleum and Energy be redeemed at the next annual general Norwegian State to maintain their ownership percentage in Equinor. The first order in the open market was concluded in September 2021. The second order in the 2022. As of 31 December, USD 99 been settled, while USD 232 330 222 million has been settled. Due to the irrevocable agreement with the third party, both the first and second order in the open market, in total USD 429 been recognised as a reduction in equity as treasury shares. The remaining order of the second tranche has along with acquired shares not settled, classified as Trade, other payables and provisions. The recognition of the State’s share will be deferred until the decision at the annual general meeting in May 2022. On 8 February 2022, the Board announced an annual share buy-back programme for 2022 with 5.0 shares to be redeemed from the Norwegian State, subject to authorisation from the annual general meeting. back programme is expected to be executed when Brent Blend oil price is in or above the range 50 - 60 to capital employed adjusted stays within the communicated ambition of 15 - 30 purpose of the share buy-back programme is to reduce the issued share capital of the company. All shares repurchased as part of the programme will be cancelled. On 8 February 2022, the board of directors resolved the commencement of the first tranche 2022 of a total of USD 1.0 25 March 2022.. Number of shares 2021 2020 Share buy-back programme at 1 January 0 23,578,410 Purchase 13,460,292 3,142,849 Cancellation 0 (26,721,259) Share buy-back programme at 31 December 13,460,292 0 Employees share saving plan Number of shares 2021 2020 Share saving plan at 1 January 11,442,491 10,074,712 Purchase 3,412,994 4,604,106 Allocated to employees (2,744,381) (3,236,327) Share saving plan at 31 December 12,111,104 11,442,491 In 2021 and 2020 treasury shares were purchased and allocated to employees participating in the share saving 75 million and USD 68

Finance debt

Finance debt	12 Months Ended
	Dec. 31, 2021
Finance debt [abstract]
Disclosure of finance debt [text block]	19 Finance debt Non-current finance debt Finance debt measured at amortised cost Weighted average interest rates in % 1) Carrying amount in USD millions at 31 December Fair value in USD millions at 31 December 2) 2021 2020 2021 2020 2021 2020 Unsecured bonds United States Dollar (USD) 3.88 3.82 17,451 18,710 19,655 21,883 Euro (EUR) 1.42 2.03 7,925 10,057 8,529 11,115 Great Britain Pound (GBP) 6.08 6.08 1,852 1,877 2,674 2,949 Norwegian Kroner (NOK) 4.18 4.18 340 352 380 412 Total unsecured bonds 27,568 30,994 31,237 36,359 Unsecured loans Japanese Yen (JPY) 4.30 4.30 87 97 106 119 Total unsecured loans 87 97 106 119 Total 27,655 31,091 31,343 36,479 Non-current finance debt due within one year 250 1,974 268 2,062 Non-current finance debt 27,404 29,118 31,075 34,417 Weighted average interest rates are calculated based on the contractual rates on the loans per currency at 31 December not include the effect of swap agreements. 2) level 2 in the fair value hierarchy. For more information regarding fair value hierarchy, see note 26 Financial Instruments: fair value measurement and sensitivity of market risk. Unsecured bonds amounting to USD 17.451 amounting to USD 9.271 0.846 swapped. The table does not include the effects of agreements entered into to swap the various currencies into USD. information see note 26 Financial instruments: fair value measurement and sensitivity analysis of Substantially all unsecured bonds and unsecured bank loan agreements contain provisions restricting future secure borrowings without granting a similar secured status to the existing bondholders and lenders. In 2020 and 2021 Equinor issued the following Issuance date Currency Amount in million Interest rate in % Maturity date 18 May 2020 USD 750 1.750 January 2026 18 May 2020 EUR 750 0.750 May 2026 18 May 2020 USD 750 2.375 May 2030 18 May 2020 EUR 1,000 1.375 May 2032 1 April 2020 USD 1,250 2.875 April 2025 1 April 2020 USD 500 3.000 April 2027 1 April 2020 USD 1,500 3.125 April 2030 1 April 2020 USD 500 3.625 April 2040 1 April 2020 USD 1,250 3.700 April 2050 No new bonds were issued in 2021. Out of Equinor's total outstanding unsecured bond portfolio, 39 bond agreements contain provisions allowing Equinor prior to its final redemption at par or at certain specified premiums if there are changes to amount of these agreements is USD 27.223 For more information about the revolving credit facility, maturity profile for undiscounted cash flows and interest rate risk management, see note 6 Financial risk and capital management. Non-current finance debt maturity profile At 31 December (in USD million) 2021 2020 Year 2 and 3 5,015 3,705 Year 4 and 5 4,731 4,927 After 5 years 17,659 20,485 Total repayment of non-current finance debt 27,404 29,118 Weighted average maturity (years - including current portion) 10 10 Weighted average annual interest rate (% - including current portion) 3.33 3.38 Current finance debt At 31 December (in USD million) 2021 2020 Collateral liabilities 2,271 1,704 Non-current finance debt due within one year 250 1,974 Other including US Commercial paper program 2,752 913 Total current finance debt 5,273 4,591 Weighted average interest rate (%) 0.51 2.40 Collateral liabilities and other current liabilities mainly relate to cash received as security for outstanding amounts on US Commercial paper (CP) programme. Issuance on the CP programme 2.600 of 31 December 2021 and USD 0.903 Reconciliation of cash flows from financing activities (in USD million) Non-current finance debt Current finance debt Financial receivable Collaterals 1) Additional paid in capital /Treasury shares Non- controlling interest Dividend payable Lease liabilities 2) Total At 1 January 2021 29,118 4,591 (967) (1,588) 19 357 4,406 New finance debt Repayment of finance debt (2,675) (2,675) Repayment of lease liabilities (1,238) (1,238) Dividend paid (1,797) (1,797) Share buy-back (321) (321) Net current finance debt and other finance activities (335) 2,273 (651) (75) (18) 1,195 Net cash flow from financing activities (3,010) 2,273 (651) (396) (18) (1,797) (1,238) (4,836) Transfer to current portion 1,724 (1,724) Effect of exchange rate changes (422) (8) 41 (1) (61) Dividend declared 2,041 New leases 476 Other changes (6) 141 (43) 14 (19) (21) Net other changes 1,296 (1,591) 41 (43) 13 2,022 394 At 31 December 2021 27,404 5,273 (1,577) (2,027) 14 582 3,562 (in USD million) Non-current finance debt Current finance debt Financial receivable Collaterals 1) Additional paid in capital /Treasury shares Non- controlling interest Dividend payable Lease liabilities 2) Total At 1 January 2020 21,754 2,939 (634) (708) 20 859 4,339 New finance debt 8,347 8,347 Repayment of finance debt (2,055) (2,055) Repayment of lease liabilities (1,277) (1,277) Dividend paid (2,330) (2,330) Share buy-back (1,059) (1,059) Net current finance debt and other finance activities 72 1,706 (329) (69) (16) 1,365 Net cash flow from financing activities 6,364 1,706 (329) (1,128) (16) (2,330) (1,277) 2,991 Transfer to current portion 30 (30) Effect of exchange rate changes 977 (27) 15 Dividend declared 1,833 New leases 1,349 Other changes (8) 3 (4) 248 15 (20) (5) Net other changes 999 (54) (4) 248 15 1,828 1,344 At 31 December 2020 29,118 4,591 (967) (1,588) 19 357 4,406 1) Financial receivable collaterals are included in other receivables for more information. 2) See note 23 Leases for more information.

Pensions

Pensions	12 Months Ended
	Dec. 31, 2021
Disclosure of defined benefit plans [abstract]
Disclosure of employee benefits [text block]	20 Pensions The main pension plans for Equinor ASA and its most significant subsidiaries are defined contribution plans, in which the pension costs are recognised in the Consolidated statement of income in line with payments of annual pension premiums. The pension contribution plans in Equinor ASA also includes certain unfunded elements (notional contribution plans), for which the annual notional contributions are recognised as pension liabilities. the main contribution plan. See note 2 Significant accounting policies to the Consolidated financial about the accounting treatment of the notional contribution plans reported in Equinor ASA. In addition, Equinor ASA has a defined benefit plan. This benefit plan was closed in 2015 for more than 15 year to regular retirement age. Equinor's defined benefit plans are generally based on a minimum of 30 years of service and 66% of the final salary level, including an assumed benefit from the Norwegian National Insurance Scheme. companies in the group are subject to, and complies with, the requirements of the Norwegian The defined benefit plans in Norway are managed and financed through Equinor Pensjon (Equinor's Pension). Equinor Pension is an independent pension fund that covers the employees in Equinor's Norwegian pension fund's assets are kept separate from the company's and group companies' assets. Equinor Pension Financial Supervisory Authority of Norway ("Finanstilsynet") and is licenced to operate as a pension fund. Equinor is a member of a Norwegian national agreement-based early retirement plan (“AFP”), and the premium is calculated based on the employees' income, but limited to 7.1 times the basic amount in the National Insurance scheme (7.1 G). for all employees until age 62 . Pension from the AFP scheme will be paid from the AFP plan administrator to lifetime. Equinor has determined that its obligations under this multi-employer defined benefit plan reliability for recognition purposes. Accordingly, the estimated proportionate share of the AFP plan is recognised as a defined benefit obligation. The present values of the defined benefit obligation, except for the notional contribution plan, and the past service cost are measured using the projected unit credit method. The assumptions payments and social security base amount are based on agreed regulation in the plans, historical the assumptions and the relationship between these assumptions. At 31 December 2021, the plans in Norway was established on the basis of seven years' mortgage covered bonds interest rate which matches the duration of Equinor's payment portfolio for earned benefits, which was calculated to 15.2 2021. Social security tax is calculated based on a pension plan's net funded status and is included The recognition of a net surplus for the funded plan is based on the assumption that the net assets Equinor, either as possible distribution to premium fund which can be used for future funding of new liabilities, or disbursement of equity in the pension fund. Equinor has more than one defined benefit plan, but the disclosure is made in total since different risks. Pension plans outside Norway are not material and as such not disclosed separately. The tables in this note present pension costs on a gross basis, before allocation to licence partners. In the Consolidated statement Equinor ASA are presented net of costs allocated to licence partners. Net pension cost (in USD million) 2021 2020 2019 Current service cost 209 184 206 Past service cost 3 - - Losses/(gains) from curtailment, settlement or plan - - 3 Notional contribution plans 60 55 56 Defined benefit plans 272 238 265 Defined contribution plans 213 192 182 Total net pension cost 488 432 446 In addition to the pension cost presented in the table above, financial items related to Consolidated statement of income within Net financial items. Interest cost and changes in fair value of amounts to USD 238 203 106 and USD 117 Changes in defined benefit obligations (DBO) and (in USD million) 2021 2020 DBO at 1 January 9,216 8,363 Current service cost 208 184 Interest cost 238 203 Actuarial (gains)/losses - Financial assumptions 294 443 Actuarial (gains)/losses - Experience (66) (61) Past service cost 3 - Benefits paid (295) (250) Paid-up policies - (7) Foreign currency translation effects (300) 286 Changes in notional contribution liability 60 55 DBO at 31 December 9,358 9,216 Fair value of plan assets at 1 January 6,234 5,589 Interest income 106 117 Return on plan assets (excluding interest income) 291 385 Company contributions 114 96 Benefits paid (137) (113) Paid-up policies and personal insurance - (7) Foreign currency translation effects (204) 167 Fair value of plan assets at 31 December 6,404 6,234 Net pension liability at 31 December (2,954) (2,981) Represented by: Asset recognised as non-current pension assets 1,449 1,310 Liability recognised as non-current pension liabilities (4,403) (4,292) DBO specified by funded and unfunded pension plans 9,359 9,216 Funded 4,959 4,927 Unfunded 4,400 4,288 Actual return on assets 397 501 Equinor recognised an actuarial loss from changes in financial assumptions in 2021, mainly due to a larger compensation increase and expected rate of pension increase compared to the other assumptions. in 2020. Actuarial losses and gains recognised directly (in USD million) 2021 2020 2019 Net actuarial (losses)/gains recognised in OCI 63 3 401 Foreign currency translation effects 84 (109) 27 Tax effects of actuarial (losses)/gains recognised in OCI (35) 19 (98) Recognised directly in OCI during the year, net of tax 112 (87) 330 Cumulative actuarial (losses)/gains recognised directly (787) (899) (812) Actuarial assumptions Assumptions used to determine benefit costs in % Assumptions used to determine benefit obligations in % Rounded to the nearest quartile 2021 2020 2021 2020 Discount rate 1.75 2.25 2.00 1.75 Rate of compensation increase 2.00 2.25 2.50 2.00 Expected rate of pension increase 1.25 1.50 1.75 1.25 Expected increase of social security base amount (G-amount) 2.00 2.25 2.25 2.00 Weighted-average duration of the defined benefit obligation 15.2 15.6 The assumptions presented are for the Norwegian companies in Equinor which are members of Equinor's pension benefit plans of other subsidiaries are immaterial to the consolidated pension assets and liabilities. Expected attrition at 31 December 2021 was 0.3% and 3.9% for employees between 50-59 years and 60-67 years, and 0.3% and 3.6% in 2020. The attrition rate for the age group 60-67 years represents employees with immediate withdrawal of vested pension, thus remaining in the scheme. For population in Norway, the mortality table K2013, issued by The Financial Supervisory Authority of Norway, is used as the best mortality estimate. Disability tables for plans in Norway developed by the actuary were implemented in 2013 plans in Norway. Sensitivity analysis The table below presents an estimate of the potential effects of changes in the key assumptions for the defined benefit plans. following estimates are based on facts and circumstances as of 31 December 2021. Discount rate Expected rate of compensation increase Expected rate of pension increase Mortality assumption (in USD million) 0.50% -0.50% 0.50% -0.50% 0.50% -0.50% + 1 year - 1 year Effect on: Defined benefit obligation at 31 December 2021 (645) 731 157 (150) 601 (545) 367 (330) Service cost 2022 (20) 24 10 (9) 16 (14) 8 (7) The sensitivity of the financial results to each of the key assumptions has been estimated factors would remain unchanged. The estimated effects on the financial result would differ from those that would Consolidated financial statements because the Consolidated financial statements would also reflect the assumptions. Pension assets The plan assets related to the defined benefit plans were measured at fair value. Equinor Pension invests real estate. The table below presents the portfolio weighting as approved by the board of Equinor Pension for year will depend on the risk capacity. Pension assets on investments classes Target portfolio weight (in %) 2021 2020 Equity securities 34.1 34.1 29-38 Bonds 50.2 50.2 46-59 Money market instruments 9.1 9.4 0-14 Real estate 6.6 6.4 5-10 Other assets, including derivatives 0.0 (0.1) Total 100.0 100.0 In 2021, 61 % of the equity securities and 3 % of bonds had quoted market prices in an active market. 37 % of the equity securities, 97 % of bonds and 100 % of money market instruments had market prices based on inputs other than quoted prices are not available, fair values are determined from external calculation models based on market sources. In 2020, 81 % of the equity securities and 2 % of bonds had quoted market prices in an active market. 17 % of the equity securities, 98 % of bonds and 100 % of money market instruments had market prices based on inputs other than quoted For definition of the various levels, see note 26 Financial instruments: fair value measurement Company contributions to be made to Equinor Pension in 2022 are expected to be in the range 100 110

Provisions and other liabilitie

Provisions and other liabilities	12 Months Ended
	Dec. 31, 2021
Provisions and other liabilities [abstract]
Provisions and other liabilities [text block]	21 Provisions and other liabilities (in USD million) Asset retirement obligations Claims and litigations Other provisions and liabilities Total Non-current portion at 31 December 2020 before 17,200 96 2,436 19,731 Impact of ARO policy change 2,837 - - 2,837 Non-current portion at 31 December 2020 after restatement 20,037 96 2,436 22,568 Current portion at 31 December 2020 reported provisions 92 958 1,600 2,649 Provisions and other liabilities at 31 December 2020 20,128 1,053 4,035 25,216 New or increased provisions and other liabilities 602 30 352 984 Change in estimates (1,097) (58) (141) (1,296) Amounts charged against provisions and other liabilities (125) (870) (524) (1,519) Effects of change in the discount rate (1,610) - (13) (1,623) Reduction due to divestments (359) - - (359) Accretion expenses 423 - 29 452 Reclassification and transfer (74) - 298 224 Foreign currency translation effects (471) - (5) (476) Provisions and other liabilities at 31 December 2021 17,417 155 4,031 21,603 Non-current portion at 31 December 2021 17,279 81 2,539 19,899 Current portion at 31 December 2021 reported provisions 138 73 1,493 1,704 Due to significantly reduced expected use of a transportation agreement, Equinor provided a liability of USD 166 onerous contract. In the third quarter 2021, this provision has been settled resulting in a the remaining amount of the provision. The reversal of the provision is reflected within the line item Consolidated statement of income. The timing of cash outflows of asset retirement obligations depends on the expected production cease at In certain production sharing agreements (PSA), Equinor’s estimated share of asset retirement account over the producing life of the field. These payments are considered down-payments of the Amounts charged against provisions and other liabilities. The Claims and litigations category mainly relate to expected payments for unresolved claims. The timing settlements in respect of these claims are uncertain and dependent on various factors that are outside management's further information on provisions and contingent liabilities, see note 24 Other commitments, contingent assets. For further information about methods applied and estimates required, see note 2 Significant accounting Line items impacted in the consolidated balance sheet (in USD million) 01.01.2020 before restatement Impact of ARO policy change 01.01.2020 after restatement 31.12.2020 before restatement Impact of ARO policy change 31.12.2020 after restatement PPE 69,953 1,798 71,751 65,672 2,836 68,508 Total non-current assets 93,285 1,798 95,083 89,786 2,836 92,623 Total assets 118,063 1,798 119,861 121,972 2,836 124,809 Provisions and other liabilities 17,951 1,798 19,749 19,731 2,837 22,568 Total non-current liabilities 57,346 1,798 59,144 68,260 2,837 71,097 Total liabilities 76,904 1,798 78,702 88,081 2,837 90,917 Expected timing of cash outflows (in USD million) Asset retirement obligations Other provisions and liabilities, including claims and litigations Total 2022 - 2026 1,180 3,014 4,194 2027 - 2031 1,597 299 1,896 2032 - 2036 4,315 248 4,563 2037 - 2041 6,152 55 6,207 Thereafter 4,173 569 4,742 At 31 December 2021 17,417 4,186 21,603

Trade, other payables and provi

Trade, other payables and provisions	12 Months Ended
	Dec. 31, 2021
Trade, other payables and provisions [abstract]
Disclosure of trade, other payables and provisions [text block]	22 Trade, other payables and provisions At 31 December (in USD million) 2021 2020 Trade payables 6,249 2,748 Non-trade payables and accrued expenses 2,181 2,352 Joint venture payables 1,876 2,090 Payables to equity accounted associated companies 2,045 546 Total financial trade and other payables 12,351 7,736 Current portion of provisions and other non-financial 1,960 2,774 Trade, other payables and provisions 14,310 10,510 Included in Current portion of provisions and other non-financial payables are certain provisions that Provisions and other liabilities and in note 24 Other commitments, regarding currency sensitivities, see note 26 Financial instruments: fair value measurement and further information on payables to equity accounted associated companies and other related parties, see

Leases

Leases	12 Months Ended
	Dec. 31, 2021
Leases [abstract]
Disclosure of leases [text block]	23 Leases Equinor leases certain assets, notably drilling rigs, transportation vessels, storages and office facilities for operational activities. Equinor is mostly a lessee and the use of leases serves operational purposes rather than as Certain leases, such as land bases, supply vessels, helicopters and office buildings are entered into by Equinor for subsequent allocation of costs to licences operated by Equinor. These lease liabilities are recognized on a gross basis in the balance sheet, income statement and statement of cash flows when Equinor is considered to have the primary responsibility payments. Lease liabilities related to assets dedicated to specific licences, where each licence primary responsibility for lease payments, are reflected net of partner share. This would typically involve drilling specific licences on the Norwegian continental shelf. Information related to lease payments and lease (in USD million) 2021 2020 Lease liabilities at 1 January 4,406 4,339 New leases, including remeasurements and cancellations 476 1,349 Gross lease payments (1,350) (1,415) Lease interest 91 102 Lease repayments (1,259) (1,259) (1,313) (1,313) Foreign currency translation effects (61) 31 Lease liabilities at 31 December 3,562 4,406 Current lease liabilities 1,113 1,186 Non-current lease liabilities 2,449 3,220 Lease expenses not included in lease liabilities (in USD million) 2021 2020 Short-term lease expenses 160 342 Payments related to short term leases are mainly related to drilling rigs and transportation the lease costs have been included in the cost of other assets, such as rigs used lease expense and lease expense related to leases of low value assets are not significant. Equinor recognised revenues of USD 272 252 partners related to lease contracts being recognised gross by Equinor. In addition, Equinor received repayments of USD 4 2021 and USD 29 USD 104 38 Trade and other receivables in the Consolidated balance sheet. Commitments relating to lease contracts which had not yet commenced at year-end are included Other commitments, contingent liabilities and contingent assets. A maturity profile based on undiscounted contractual cash flows for lease liabilities is management. Non-current lease liabilities maturity profile At 31 December (in USD million) 2021 2020 Year 2 and 3 1,164 1,513 Year 4 and 5 586 748 After 5 years 699 959 Total repayment of non-current lease liabilities 2,449 3,220 Information related to Right of use assets (in USD million) Drilling rigs Vessels Land and buildings Storage facilities Other Total Right of use assets at 1 January 2021 1,004 1,606 1,215 133 161 4,119 Additions, divestments 14 300 28 8 78 427 Depreciation and impairment 1) (316) (617) (176) (72) (82) (1,265) Foreign currency translation effects (26) (8) (12) 0 (5) (50) Right of use assets at 31 December 2021 675 1,280 1,055 68 152 3,231 (in USD million) Drilling rigs Vessels Land and buildings Storage facilities Other Total Right of use assets at 1 January 2020 951 1,320 1,365 156 219 4,011 Additions, divestments 380 853 18 45 30 1,326 Depreciation and impairment 1) (349) (571) (179) (68) (90) (1,257) Foreign currency translation effects 23 4 11 0 2 40 Right of use assets at 31 December 2020 1,004 1,606 1,215 133 161 4,119 1) USD 320 million in 2021 and USD 359 11 Property, The Right of use assets are included within the line item Property, plant and equipment in the Consolidated balance sheet. See also note 11 Property,

Other commitments, contingent l

Other commitments, contingent liabilities and contingent assets	12 Months Ended
	Dec. 31, 2021
Disclosure of other commitments, contingent liabilities and contingent assets [abstract]
Disclosure of other commitments, contingent liabilities and contingent assets [text block]	24 Other commitments, contingent liabilities and contingent Contractual commitments Equinor had contractual commitments of USD 7.038 proportional share and mainly comprise construction and acquisition of property, plant and equipment as well as committed investments/funding or resources in equity accounted entities. As a condition for being awarded oil and gas exploration and production licences, participants may be number of wells. At the end of 2021, Equinor was committed to participate in 36 approximately 46 %. Equinor's share of estimated expenditures to drill these wells amounts to USD 409 Equinor may become committed to participating in depending on future discoveries in certain licences numbers. Other long-term commitments Equinor has entered into various long-term agreements for pipeline transportation as well as terminal use, processing, entry/exit capacity commitments and commitments related to specific purchase agreements. The capacity or volumes in question, but also impose on Equinor the obligation to pay for the agreed-upon irrespective of actual use. The contracts' terms vary, with durations of up to 2060 . Take-or-pay contracts for the purchase of commodity quantities are only included in the table below if their contractually agreed pricing is of a nature that will or may deviate from the obtainable market prices for the Obligations payable by Equinor to entities accounted for in the Equinor group using the equity method with Equinor’s operations or similar arrangements, and where consequently Equinor’s share of costs) are reflected on a line-by-line basis in the Consolidated financial statements, the amounts in the table commitment payable by Equinor (i.e. Equinor’s proportionate share of the applicable entity). The table below also includes USD 2.022 according to IFRS 16, as well as leases not yet commenced. Leases not commenced include one rig to be used increased number of vessels supporting the growing LPG and LNG business. For commenced leases, please Nominal minimum other long-term commitments at 31 December 2021: (in USD million) 2022 2,663 2023 2,077 2024 1,520 2025 1,307 2026 1,026 Thereafter 4,547 Total other long-term commitments 13,140 Guarantees Equinor has guaranteed for its proportionate share of some of our associate’s long-term bank debt, payment obligations contracts, and certain third-party obligations. The total amount guaranteed at year-end 2021 is USD 439 guarantees is immaterial. Contingent liabilities and contingent assets Redetermination process for Agbami field Through its ownership in OML 128 in Nigeria, Equinor is a party to an ownership interest redetermination which will reduce Equinor’s ownership interest. A non-binding agreement for fourth quarter of 2018. The parties to the non-binding agreement have thereafter continued agreed-upon ownership percentage adjustment. In June 2021, Equinor paid a total of USD 822 Agbami Unit. The payment covered outstanding amounts between the three parties as of 31 March adjustment to the previous provision by USD 57 remaining Agbami redetermination related provision reflected in Trade and other payables in the Consolidated balance sheet at year- end is immaterial. Mineral rights dispute along the Missouri riverbank Equinor produces minerals from wells in spacing units along the Missouri River in which with the near shore region up to the ordinary high-water mark has been disputed. As operator of right to part of the proceeds, and a responsibility to distribute the remainder of the proceeds mineral rights. As the riverbank has moved continuously over time, updated river-surveys have resulted in interest parties, including the State of North Dakota, the United States, and private parties. During received updated title opinions reflecting the latest State survey that resulted in clarification among the main procedural matters remain, but Equinor’s maximum exposure in the case was Amounts reflected in the matter in the Consolidated balance sheet at 31 December during the year 2021 are immaterial. Claim from Petrofac regarding multiple variation order requests performed in Algeria (In Salah) Petrofac International (UAE) LLC (“PIUL”) was awarded the EPC Contract to execute the ISSF Project which has finalized the development of 4 gas fields in central Algeria). Following suspension at another gas field in Algeria (In Amenas) in 2013, PIUL issued multiple Variation Order Requests (“VoRs”) related to the costs incurred for stand-by and remobilization costs after the evacuation of expatriates. Several VoRs have been paid, but the settlement of the remaining has been unsuccessful. PIUL initiated arbitration in August 2020 claiming an estimated amount of USD 533 which Equinor holds a 31.85 % share. Equinor's maximum exposure amounts to USD 163 estimate in the matter. Withholding tax dispute regarding remittances from Brazil to Norway Remittances made from Brazil for services are normally subject to withholding income tax. filed a lawsuit to avoid paying this tax on remittances made to Equinor ASA and Equinor Energy technology based on the Double Tax Treaty Brazil has with Norway. since 2014, withholding tax has not been paid. In 2017, a second level decision was rendered decision was appealed. The trial session concluded in July 2021, overruling the previous favourable aspects only. Equinor has filed a motion for clarification which had the effect of temporarily suspending the unfavourable decision and is currently awaiting the court’s decision, on the basis of which Equinor’s further legal steps in the maximum exposure is estimated at approximately USD 135 applied in the case and that Equinor has a strong position. No amounts have consequently statements. Suit for an annulment of Petrobras’ sale of the interest in BM-S-8 to Equinor In March 2017, an individual connected to the Union of Oil Workers of Sergipe (Sindipetro) filed a Equinor, and ANP - the Brazilian Regulatory Agency - to seek annulment of Petrobras’ sale of the interest and operatorship in BM-S-8 to Equinor, which was closed in November 2016 after approval by the partners and authorities. In February 2022, sentence in the annulment case was issued at the first instance level, and Equinor won on all merits. Equinor and is currently evaluation next steps. At the end of 2021, the acquired interest remains in Equinor’s assets of the Exploration & Production International (E&P International) segment. ICMS indirect tax (Imposto sobre Circulaçao de Mercadorias - Tax on the Circulation of Goods and Certain Services) In Brazil, the State of Rio de Janeiro in 2015 published a law whereby crude oil extraction 18 % ICMS indirect tax, for which the Brazilian Industry Association challenged the law’s constitutionality. In March 2021 the plenary of Brazil’s Supreme Court declared the State of Rio de Janeiro’s law to be unconstitutional, and the decision became final Supreme Court’s decision, Equinor evaluates the probability of any cash outflow in relation to the for the Roncador and Peregrino fields to be remote. The maximum exposure for Equinor is 460 million. As no provisions have previously been made in the matter, the Brazilian Supreme Court’s decision does not impact Equinor’s Consolidated financial statements for the year 2021. New Brazilian law creating uncertainty regarding certain tax incentives In 2021, a law came into effect in Brazil in the State of Rio de Janeiro, requiring taxpayers that benefited Repetro) to deposit 10 % of the savings made from such benefits into a state fund. This law had slightly different features from a previous similar law effective in the period 2017 to 2020. Equinor is of the opinion that specific incentives Roncador and Peregrino fields are not in scope of the new law, nor were they in scope of the previous one. State tax authorities in Rio de Janeiro may interpret the laws differently and require deposits to be paid with the addition of fines and interests. Several actions to oppose such developments have therefore been initiated by Equinor’s peers (IBP). So far, Equinor is party to two of the cases. At year-end 2021, the maximum exposure for Equinor in these various matters has been estimated to a total of USD 112 2022 to avoid losing ICMS tax incentives while litigation is ongoing. Equinor is of the opinion that unconstitutional, especially for Repetro incentives, and that this will be upheld in future legal proceedings. No amounts consequently been provided for in the financial statements. KKD oil sands partnership Canadian tax authorities have issued a notice of reassessment for 2014 for Equinor's Canadian Equinor's divestment of 40 allocation of the proceeds of disposition of certain Canadian resource properties from the partnership. Maximum estimated to be approximately USD 397 litigation that may become necessary, may take several years. No taxes will become payable until the matter has been finally settled. Equinor is of the view that all applicable tax regulations have been applied in the case amounts have consequently been provided for in the financial statements. Deviation notices and disputes with Norwegian tax authorities In the fourth quarter of 2020, Equinor received a decision from the Norwegian tax authorities related subsidiary Equinor Service Center Belgium N.V. The decision concludes that the capital structure has to be based on the arm length’s principle and the decision covers the fiscal years 2012 to 2016. Maximum exposure is estimated 182 for which Equinor has received a claim that was settled in 2021. Equinor has brought the the tax payment will be refunded. It continues to be Equinor’s view that the group amounts have consequently been expensed in the financial statements. Equinor has an ongoing dispute regarding the level of Research & Development cost to be allocated on Equinor’s correspondence with the Norwegian tax authorities in the matter regarding some of the income years, the maximum exposure in this matter is estimated to 206 has provided for its best estimate in the matter. The Oil Taxation Office has challenged the internal pricing of certain products of natural gas liquids sold from Equinor Energy AS to Equinor ASA in the years 2011-2020. During 2021 there has been development is various elements of the case, where parts of the exposure are resolved, level court proceedings are scheduled in June 2022. Other parts of the dispute remain outstanding. period 2020–2021 has been added. Following these developments, which did not impact the Consolidated significantly, the maximum exposure regarding the gas liquid pricing remains at an estimated USD 100 for its best estimate in the matter. Other claims During the normal course of its business, Equinor is involved in legal proceedings, and several other unresolved outstanding. The ultimate liability or asset, in respect of such litigation and claims cannot provided in its Consolidated financial statements for probable liabilities related to litigation and Equinor does not expect that its financial position, results of operations or cash flows will be materially these legal proceedings. Equinor is actively pursuing the above disputes through the contractual case, but the timing of the ultimate resolutions and related cash flows, if any, cannot at present be determined with sufficient reliability. Provisions related to claims other than those related to income tax are reflected within note 21 Provisions Uncertain income tax related liabilities are reflected as current tax payables or deferred tax tax assets are reflected as current or deferred tax assets.

Related parties

Related parties	12 Months Ended
	Dec. 31, 2021
Disclosure of related parties [abstract]
Disclosure of related party [text block]	25 Related parties Transactions with the Norwegian State The Norwegian State is the majority shareholder of Equinor and also holds major investments 31 December 2021, the Norwegian State had an ownership interest in Equinor of 67.0 % (excluding Folketrygdfondet, the Norwegian national insurance fund, of 3.7 %). This ownership structure means that Equinor participates in transactions under a common ownership structure and therefore meet the definition of a related party. The Minister of Trade, Industry and Fisheries took over the constitutional responsibility for following-up of the Norwegian State`s ownership July 2021. The responsibility for the Norwegian State`s shareholding in Equinor has been transferred and Energy to the Ministry of Trade and Industry on 1 January 2022. Total purchases of oil and natural gas liquids from the Norwegian State amounted to USD 9.572 5.108 7.505 the Norwegian State amounted to USD 0.088 0.018 0.036 These purchases of oil and natural gas are recorded in Equinor ASA. In addition, Equinor Norwegian State’s account and risk, the Norwegian State’s gas production. These transactions are presented net. For further information please see note 2 Significant accounting policies. The most significant items included accounted associated companies and other related parties in note 22 Trade and other payables, are amounts payable to the Norwegian State for these purchases. The line-item Prepayments and Financial Receivables includes USD 0.435 Norwegian state under the Marketing Instruction in relation to the state’s (SDFI) expected participation in the gas foreign subsidiary of Equinor. At year end 2020 the corresponding amount was USD 0.169 In July 2021 Equinor launched the first tranche of around USD 300 USD 600 Other transactions In relation to it ordinary business operations Equinor enters into contracts such as pipeline transport, gas petroleum products, with companies in which Equinor has ownership interests. Such transactions are captions in the Consolidated statement of income. Gassled and certain other infrastructure is an entity under common control by the Norwegian Ministry of Petroleum and Energy. Gassco’s activities are performed on behalf of and for the risk and reward of pipeline and terminal owners, and capacity payments flow Equinor payments that flowed through Gassco in this respect amounted to USD 1.030 0.896 1.076 in 2021, 2020 and 2019, respectively. These payments are mainly recorded in Equinor ASA. The stated amounts represent Equinor’s capacity payment net of Equinor’s own ownership interests in Gassco operated infrastructure. In its own name, but for the Norwegian State’s account and risk, the Norwegian State’s share of the Gassco costs. These are presented net. Equinor has had transactions with other associated companies and joint ventures in relation to its which amounts have not been disclosed due to materiality. Equinor leases two office buildings, located in Bergen and Harstad, owned by Equinor’s The lease contracts extend to the years 2034 and 2037 284 contracts. Related party transactions with management are presented in note 7 Remuneration .

Financial instruments_ fair val

Financial instruments: fair value measurement and sensitivity analysis of market risk	12 Months Ended
	Dec. 31, 2021
Disclosure of Financial instruments: fair value measurement and sensitivity analysis of market risk [abstract]
Disclosure of Financial instruments: fair value measurement and sensitivity analysis of market risk [text block]	26 Financial instruments: fair value measurement and sensitivity Financial instruments by category The following tables present Equinor's classes of financial instruments and their carrying amounts by the categories as defined in IFRS 9 Financial Instruments: Classification and Measurement. measurement as defined by IFRS 9 categories and measurement at fair value is immaterial. For trade payables, and cash and cash equivalents, the carrying amounts are considered a reasonable approximation Finance debt for fair value information of non-current bonds and bank loans. See note 2 Significant accounting policies for further information regarding measurement of fair values. At 31 December 2021 Fair value through profit or loss Non-financial assets Total carrying amount (in USD million) Note Amortised cost Assets Non-current derivative financial instruments 1,265 1,265 Non-current financial investments 14 253 3,093 3,346 Prepayments and financial receivables 14 707 380 1,087 Trade and other receivables 16 17,192 736 17,927 Current derivative financial instruments 5,131 5,131 Current financial investments 14 20,946 300 21,246 Cash and cash equivalents 17 11,412 2,714 14,126 Total financial assets 50,510 12,503 1,116 64,128 At 31 December 2020 Fair value through profit or loss Non-financial assets Total carrying amount (in USD million) Note Amortised cost Assets Non-current derivative financial instruments 2,476 2,476 Non-current financial investments 14 261 3,822 4,083 Prepayments and financial receivables 1) 14 465 396 861 Trade and other receivables 16 7,418 814 8,232 Current derivative financial instruments 886 886 Current financial investments 14 11,649 216 11,865 Cash and cash equivalents 17 6,264 492 6,757 Total financial assets 26,057 7,892 1,210 35,159 1) The categories Amortised cost and Non-financial assets incorrect classification of USD 32 million in 2020. At 31 December 2021 Amortised cost Fair value through profit or loss Non-financial liabilities Total carrying amount (in USD million) Note Liabilities Non-current finance debt 19 27,404 27,404 Non-current derivative financial instruments 767 767 Trade, other payables and provisions 22 12,350 1,960 14,310 Current finance debt 19 5,273 5,273 Dividend payable 582 582 Current derivative financial instruments 4,609 4,609 Total financial liabilities 45,609 5,376 1,960 52,945 At 31 December 2020 Amortised cost Fair value through profit or loss Non-financial liabilities Total carrying amount (in USD million) Note Liabilities Non-current finance debt 19 29,118 29,118 Non-current derivative financial instruments 676 676 Trade, other payables and provisions 22 7,736 2,774 10,510 Current finance debt 19 4,591 4,591 Dividend payable 357 357 Current derivative financial instruments 1,710 1,710 Total financial liabilities 41,802 2,386 2,774 46,961 Fair value hierarchy The following table summarises each class of financial instruments which are recognised in the value, split by Equinor's basis for fair value measurement. (in USD million) Non-current financial investments Non-current derivative financial instruments - assets Current financial investments Current derivative financial instruments - assets Cash equivalents Non-current derivative financial instruments - liabilities Current derivative financial instruments - liabilities Net fair value At 31 December 2021 Level 1 860 0 - 949 0 (69) 1,740 Level 2 1,840 884 300 4,108 2,714 (762) (4,539) 4,545 Level 3 393 380 74 (4) 843 Total fair value 3,093 1,265 300 5,131 2,714 (767) (4,609) 7,127 At 31 December 2020 Level 1 1,379 - 66 419 - (432) 1,432 Level 2 2,135 2,146 150 443 492 (671) (1,277) 3,418 Level 3 308 330 24 (5) 657 Total fair value 3,822 2,476 216 886 492 (676) (1,710) 5,505 Level 1, fair value based on prices quoted in an active market for identical assets or liabilities, traded and for which the values recognised in the Consolidated balance sheet are determined instruments. For Equinor this category will, in most cases, only be relevant for investments in listed bonds. Level 2, fair value based on inputs other than quoted prices included within level 1, which are derived from transactions, includes Equinor's non-standardised contracts for which fair values are determined on the basis observable market transactions. This will typically be when Equinor uses forward prices on crude foreign currency exchange rates as inputs to the valuation models to determine the fair value of it derivative Level 3, fair value based on unobservable inputs, includes financial instruments for which fair input and assumptions that are not from observable market transactions. The fair values presented on internal assumptions. The internal assumptions are only used in the absence of quoted observable price inputs for the financial instruments subject to the valuation. The fair value of certain earn-out agreements and embedded derivative contracts are determined with price inputs from observable market transactions as well as internally generated price assumptions discount rate used in the valuation is a risk-free rate based on the applicable currency and time horizon adjusted for a credit premium to reflect either Equinor's credit premium, if the value is a liability, or an estimated counterparty credit premium if the value is an asset. In addition, a risk premium for risk elements not adjusted for in applicable. The fair values of these derivative financial instruments have been classified in their current derivative financial instruments and non-current derivative financial instruments. Another reasonable assumption, have been applied when determining the fair value of these contracts, would be to extrapolate the inflation. If Equinor had applied this assumption, the fair value of the contracts included would 0.4 0.1 The reconciliation of the changes in fair value during 2021 and 2020 for financial instruments classified as level presented in the following table. (in USD million) Non-current financial investments Non-current derivative financial instruments - assets Current derivative financial instruments - assets Non-current derivative financial instruments - liabilities Total amount Opening at 1 January 2021 308 330 24 (5) 657 Total gains and losses recognised in statement of income (23) 58 72 1 108 Purchases 119 119 Settlement (7) (20) (27) Transfer out of level 3 - - Foreign currency translation effects (3) (8) (2) (13) Closing at 31 December 2021 394 380 74 (4) 844 Opening at 1 January 2020 277 219 33 (19) 510 Total gains and losses recognised in statement of income (29) 106 19 14 109 Purchases 64 64 Settlement (8) (28) (36) Transfer to level 1 1 1 Foreign currency translation effects 4 5 - 9 Closing at 31 December 2020 308 330 24 (5) 657 During 2021 the financial instruments within level 3 have had a net increase in fair value of USD 187 financial investments contributed with USD 86 108 during 2021 are mainly related to changes in fair value of certain earn-out agreements where USD 20 balance for 2021 has been fully realised as the underlying volumes have been delivered during Sensitivity analysis of market risk Commodity price risk The table below contains the commodity price risk sensitivities of Equinor's commodity based information related to the type of commodity risks and how Equinor manages these risks, see note management. Equinor's assets and liabilities resulting from commodity based derivatives contracts consist of exchange traded instruments, including embedded derivatives that have been bifurcated and recognised Consolidated balance sheet. Price risk sensitivities at the end of 2021 and 2020 at 30 % are assumed to represent a reasonably possible change based on the duration of the derivatives. Since none of the derivative financial instruments included in the relationships, any changes in the fair value would be recognised in the Consolidated Commodity price sensitivity At 31 December 2021 2020 (in USD million) - 30% + 30% - 30% + 30% Crude oil and refined products net gains/(losses) 735 (735) 1,025 (1,025) Natural gas, electricity and CO2 net gains/(losses) 227 (141) 184 (94) Currency risk The following currency risk sensitivity has been calculated, by assuming an 10% reasonable possible change foreign currency exchange rates that impact Equinor’s financial accounts, based on December 2020, a change of 8% in the most relevant foreign currency exchange rates were viewed change. With reference to table below, an increase in the foreign currency exchange rates means that the disclosed currency has strengthened in value against all other currencies. The estimated gains and the estimated losses following from foreign currency exchange rates would impact the Consolidated statement of income. For further information risk and how Equinor manages these risks, see note 6 Financial risk and capital management. Currency risk sensitivity At 31 December 2021 2020 (in USD million) - 10 % + 10% - 8 % + 8% USD net gains/(losses) (1,789) 1,789 (319) 319 NOK net gains/(losses) 2,144 (2,144) 322 (322) Interest rate risk The following interest rate risk sensitivity has been calculated by assuming a change of 0.8 percentage possible change in interest rates at the end of 2021. In 2020, a change of 0.6 percentage reasonable possible change. A decrease in interest rates will have an estimated positive impact Consolidated statement of income, while an increase in interest rates has an estimated negative impact Consolidated statement of income. For further information related to the interest risks and how Equinor manages 6 Financial risk and capital management. Interest risk sensitivity At 31 December 2021 2020 (in USD million) points + 0.8 percentage points points + 0.6 percentage points Positive/(negative) impact on net financial items 448 (448) 516 (516) Equity price risk The following equity price risk sensitivity has been calculated, impact Equinor’s financial accounts, based on balances at 31 December 2021. Also at prices were viewed as a reasonable possible change. The estimated gains and the estimated losses following prices would impact the Consolidated statement of income. For further information related to the manages these risks, see note 6 Financial risk and capital management. Equity price sensitivity At 31 December 2021 2020 (in USD million) - 35% + 35% - 35% + 35% Net gains/(losses) (534) 534 (684) 684

Subsequent events

Subsequent events	12 Months Ended
	Dec. 31, 2021
Disclosure of subsequent events [abstract]
Disclosure of Subsequent events [text block]	27 Subsequent events Equinor has certain investments in Russia. On 28 February 2022, Equinor announced it Russia and start the process of exiting Equinor’s joint arrangements in Russia 2021, Equinor had USD 1.2 proved reserves of 88 21.6 mboe/d. Equinor expects that the process of exiting the joint arrangements in Russia

Significant accounting policies

Significant accounting policies (Policies)	12 Months Ended
	Dec. 31, 2021
Significant accounting policies [Abstract]
Statement of compliance [text block]	Statement of compliance The Consolidated financial statements of Equinor ASA and its subsidiaries (Equinor) have been prepared in International Financial Reporting Standards (IFRSs) as adopted by the European Union (EU) International Accounting Standards Board (IASB), effective at 31 December 2021.
Basis of preparation [text block]	Basis of preparation The financial statements are prepared on the historical cost basis with some exceptions, as detailed below. The policies described in this note are, unless otherwise noted, in effect at the balance sheet date. These policies have been applied consistently to all periods presented in these Consolidated financial statements, related to the impact of policy changes following the adoption of new accounting standards and amounts in the comparable years have been restated or reclassified to conform to in some of the tables in the notes may not equal the sum of the amounts shown in Operating related expenses in the Consolidated statement of income are presented as a combination conformity with industry practice. Purchases [net of inventory variation] and Depreciation, amortisation and presented in separate lines based on their nature, while Operating expenses and Selling, general as Exploration expenses are presented on a functional basis. Significant expenses such as salaries, pensions, their nature in the notes to the Consolidated financial statements.
Changes in significant accounting policies in the current period [text block]	Changes in significant accounting policies in the current period Interest rate benchmark reform - amendments to IFRS 9, IAS 39, IFRS 7, IFRS 4 and Following the decision taken by global regulators to replace Interbank Offered Rates (IBORs) with alternative nearly (RFRs), IASB released two publications addressing issues affecting financial reporting in the period before the existing interest rate benchmark with an RFR (phase one), and issues that affect financial reporting when an benchmark is replaced with an RFR (phase two), typically modifications to contracts as a result provide specific guidance on how to treat financial assets and financial liabilities where the flows changes as a result of the interest rate benchmark reform. As a practical expedient, the amendments the basis for determining the contractual cash flows prospectively by revising the effective interest rate. Had the the financial instrument should be derecognised by such a contractual change, or, if the modification was insubstantial, the carrying value of the financial instrument recalculated and the adjustment recognised as a profit/loss. The phase one amendments were effective from 1 January 2020 and the phase two amendments were effective for annual beginning on or after 1 January 2021. Equinor has applied the amendments at the effective dates. For Equinor, the transition is relevant for issued bonds with floating interest rates, terms of conditions for bank accounts, project financing, legal contracts and joint venture cash calls as well as for derivatives. In collaboration with the process of replacing contracts which include references to IBORs with new contracts with references reform mainly implies an administrative burden and no material financial impact from the reform is management strategy has not changed to a significant degree following the IBOR reform.
Other standards, amendments to standards and interpretations of standards, issued but not yet effective	Other standards, amendments to standards and interpretations of standards, effective as of 1 Other standard amendments or interpretations of standards effective as of 1 January 2021 and adopted by Equinor, were not material to Equinor’s Consolidated financial statements upon adoption. Voluntary change in significant accounting policy related to discount rate for Asset Retirement Obligation (ARO) calculation With effect from 1 October 2021, Equinor changed its discount rate used in calculation of the ARO element covering Equinor’s own credit risk. This voluntary accounting policy change is made from the discount rate in estimating the ARO liability is deemed to better represent the risks affects the amounts of ARO liabilities and the ARO elements of property, plant and equipment materially, and prior periods’ balance sheet amounts in this respect have been restated, see further details in Note 21. The policy expenses as well as potential asset impairments or impairment reversals. The impact on relevant on equity upon implementation of the voluntary policy change are immaterial. Prior period income statements changes in equity have not been restated. Other standards, amendments to standards and interpretations of standards, issued but not Amendment to IAS 1 and Materiality practice statement 2: Replacing ‘Significant accounting policies’ IASB has issued an amendment to IAS 1 Presentation of financial statements and the IFRS Judgement’. These amendments are intended to help entities provide more useful accounting ‘Significant’ with the term ‘Material’ and by providing additional guidance as to what is considered implementing the amendment, even though some additions to the disclosures may be introduced specific accounting policy note, the note is expected to be somewhat reduced in scope, disclosing are deemed needed to understand other material information in the financial statements of Equinor. The amendments become effective for annual periods beginning on or after 1 January 2023, but earlier application is Equinor expects to apply the amendments from the effective date. Other standards, amendments to standards, and interpretations of standards, issued but not yet effective, are either materially impact Equinor’s Consolidated financial statements, or are not expected statements upon adoption.
Key sources of estimation uncertainty [text block]	Key sources of estimation uncertainty The preparation of the Consolidated financial statements requires that management makes reported amounts of assets, liabilities, income and expenses. The estimates are prepared based on tailormade models, assumptions on which the estimates are based rely on historical experience, external sources of information that management assesses to be reasonable under the current conditions and circumstances. These the basis of making the judgements about carrying values of assets and liabilities sources. Actual results may differ from these estimates. The estimates and underlying assumptions are reviewed on an basis considering the current and expected future set of conditions. Equinor is exposed to a number of underlying economic factors which affect the overall results, such as liquids prices, refining margins, foreign currency exchange rates, market risk premiums and interest rates with fair values derived from changes in these factors. In addition, Equinor's results are influenced the short term may be influenced by, for instance, maintenance programmes. In the long-term, the results are impacted by the success of exploration, field development and operating activities. The most important matters in understanding the key sources of estimation uncertainty Consolidated financial statements are disclosed in the following under each paragraph, where relevant Estimation uncertainty from initiatives to limit climate changes and the energy transition The effects of the initiatives to limit climate changes and the potential impact of the energy transition economic assumptions in our estimations of future cash flow. The results the development of such initiatives may have in the future, and the degree Equinor’s operations will be affected by them, are sources of uncertainty. Estimating global energy demand and commodity prices towards 2050 is a challenging task, assessing the future development in supply taxation, tax on emissions, production limits and other important factors. The assumptions may different outcomes from the current projected scenarios. This could result in significant changes to accounting economic useful life (affects depreciation period and timing of asset retirement obligations) and value-in-use calculations (affects impairment assessments). See note 3 Consequences of initiatives to limit climate changes for more
Statement of cashflows policy (text block)	Statement of cash flows In the statement of cash flows, operating activities are presented using the indirect method, where Income/(loss) for changes in inventories and operating receivables and payables, the effects of non-cash items such as depreciations, and impairments, provisions, unrealised gains and losses and undistributed profits from associates and items for which the cash effects are investing or financing cash flows. Increase/decrease in financial investments, derivative financial instruments and Increase/decrease in other interest-bearing items are all presented activities, either because the transactions are financial investments and turnover is quick, the amounts are short, or due to materiality.
Basis of consolidation [text block]	Basis of consolidation The Consolidated financial statements include the accounts of Equinor ASA and its subsidiaries jointly controlled and equity accounted investments.
Subsidiaries [text block]	Subsidiaries Entities are determined to be controlled by Equinor, and consolidated in Equinor's financial statements, when Equinor has power over the entity, ability to use that power to affect the entity's returns, and exposure to, or rights to, variable returns from its involvement with the entity. All intercompany balances and transactions, including unrealised profits and losses arising from Equinor's internal been eliminated. Non-controlling interests are presented separately within equity in the Consolidated balance sheet. When partially divesting subsidiaries which do not constitute a business, and the investment is reclassified controlled investment, Equinor only recognises the gain or loss on the divested part. Accounting judgement regarding partial divestments The policy regarding partial divestments of subsidiaries requires judgement to be applied on a case-by-case substantial impact on the accounting for the divestment of Equinor’s non-operated interests assets, which took effect in 2021 and are further described in Note 5 Acquisitions and Disposals. requirements and scope of IFRS 10 Consolidated Financial Statements and IAS 28 Investments in well as the substance of the transactions. In evaluating the standards’ requirements, Equinor acknowledged related to several relevant and similar issues which have been postponed by the IASB in later date and considered the facts and substance of the transactions in question as well assets were transferred into separate legal entities only at the time when 50% of the entities’ resulting in Equinor’s loss of control of those asset-owning subsidiaries, and simultaneously established Equinor concluded to only recognise the gain on the divested part.
Joint operations and similar arrangements, joint ventures and associates [text block]	Joint operations and similar arrangements, joint ventures and associates A joint arrangement is present where Equinor holds a long-term interest which is jointly partners under a contractual arrangement in which decisions about the relevant activities require sharing control. Such joint arrangements are classified as either joint operations or joint ventures. The parties to a joint operation have rights to the assets and obligations for the liabilities, relating arrangement. In determining whether the terms of contractual arrangements and other facts and circumstances lead as joint operations, Equinor considers the nature of products and markets of the arrangements agreements is that the parties involved have rights to substantially all the arrangement's assets. Equinor assets, liabilities, revenues and expenses in joint operations in accordance with the principles liabilities, revenues and expenses. Acquisition of ownership shares in joint ventures and other equity accounted investments in which the are accounted for in accordance with the requirements applicable to business combinations. Those of Equinor's exploration and production licence activities that are within the scope classified as joint operations. A considerable number of Equinor's unincorporated joint exploration conducted through arrangements that are not jointly controlled, either because unanimous consent involved, or no single group of parties has joint control over the activity. Licence activities where control can be achieved through agreement between more than one combination of involved parties are considered to be activities are accounted for on a pro-rata basis using Equinor's ownership share. Currently there Equinor's accounting for unincorporated licence arrangements whether in scope of IFRS 11 or not. Joint ventures, in which Equinor has rights to the net assets, are accounted for using the equity method. These majority of Equinor’s investments in the Renewables (REN) operating and reporting segment. Equinor’s participation in joint arrangements that are joint ventures and investments in nor joint control but has the ability to exercise significant influence over operating and financial accounted investments. Under the equity method, the investment is carried on the Consolidated acquisition changes in Equinor’s share of net assets of the entity, less distributions received and less any impairment in value of the investment. The part of an equity accounted investment’s dividend distribution exceeding the entity’s carrying amount in the Consolidated balance sheet is reflected as income from equity accounted investments in the Consolidated Equinor will subsequently only reflect the share of net profit in the investment that exceeds Goodwill may arise as the surplus of the cost of investment over Equinor’s share of liabilities of the joint venture or associate. Such goodwill is recorded within the corresponding of income reflects Equinor’s share of the results after tax of an equity accounted amortisation and any impairment of the equity accounted entity’s assets based on their fair values at the income/loss from equity accounted investments is presented as part of Total revenues and other income, as investments in and participation with significant influence in other companies engaged in energy-related business Equinor’s main operating activities. Where material differences in accounting policies arise, equity accounted entities are made in order to bring the accounting policies applied transactions between Equinor and its equity accounted entities are eliminated to the extent of Equinor’s accounted entity. Unrealised losses are also eliminated unless the transaction provides evidence of an impairment of the asset transferred. Equinor assesses investments in equity accounted entities for impairment whenever events or indicate that the carrying value may not be recoverable. Equinor as operator of joint operations and similar arrangements Indirect operating expenses such as personnel expenses are accumulated in cost pools. These costs incurred basis to business areas and Equinor operated joint operations under IFRS 11 and to similar arrangements (licences) outside the scope of IFRS 11. Costs allocated to the other partners' share of operated joint operations and similar arrangements reduce the costs in the Consolidated statement of income. Only Equinor's share of the statement of income Equinor-operated joint operations and similar arrangements are reflected in the Consolidated statement of income Consolidated balance sheet. The accounting for lease contracts in joint operations or similar arrangements Equinor or all partners equally have the primary responsibility for the lease payments and is described in further paragraph Leases below.
Reportable segments [text block]	Reporting segments Equinor identifies its operating segments (business areas) on the basis of those components the chief operating decision maker, Equinor's corporate executive committee (CEC). Equinor combines business areas when these satisfy relevant aggregation criteria. Equinor's accounting policies as described in this note also apply to the specific financial related disclosure in these Consolidated financial statements, with an exception for leases. Note information about lease accounting in the reporting segments.
Foreign currency translation [text block]	Foreign currency translation In preparing the financial statements of the individual entities, transactions in foreign currencies (those are translated at the foreign exchange rate at the dates of the transactions. Monetary currencies are translated to the functional currency at the foreign exchange rate at the differences arising on translation are recognised in the Consolidated statement of income as foreign exchange Net financial items. Foreign exchange differences arising from the translation of estimate-based provisions, accounted for as part of the change in the underlying estimate and as such may be included income tax sections of the Consolidated statement of income depending on the nature of the measured at historical cost in a foreign currency are translated using the exchange rate at the date Equinor ASA to subsidiaries with other functional currencies than the parent company, and for which settlement is neither planned nor likely in the foreseeable future, are considered part of the parent company’s net investment in the subsidiary. Foreign exchange differences arising on such loans are recognised in Other comprehensive income (OCI) in the Consolidated
Presentation currency [text block]	Presentation currency For the purpose of preparing the Consolidated financial statements, the statement of income, the each entity are translated from the functional currency into the presentation currency, USD. The assets and liabilities of entities whose functional currencies are other than USD, are translated into USD at the foreign exchange rate revenues and expenses of such entities are translated using the foreign exchange rates on the exchange differences arising on translation from functional currency to presentation currency are recognised separately in cumulative amount of such translation differences relating to an entity and previously recognised in OCI, is Consolidated statement of income and reflected as a part of the gain or loss on disposal of that
Business combinations [text block]	Business combinations Business combinations, except for transactions between entities under common control, are accounted for method of accounting. The acquired identifiable tangible and intangible assets, liabilities and contingent their fair values at the date of the acquisition. Acquisition costs incurred are expensed under Selling, expenses. Accounting judgement regarding acquisitions Determining whether an acquisition meets the definition of a business combination requires judgement to case basis. Acquisitions are assessed under the relevant IFRS criteria to establish whether the transaction represents combination or an asset purchase, and the conclusion may materially affect the financial statements both in in terms of future periods’ operating income. Similar assessments are performed upon the acquisition to determine whether the activity in the joint operation constitutes a business, and whether the accounting therefore should be applied. The concentration test in IFRS 3 provide some clarification do not diminish the fact that critical judgements apply when deciding on whether a transaction on the specific facts, acquisitions of exploration and evaluation licences for which a development have largely been concluded to represent asset purchases.
Revenue recognition [text block]	Revenue recognition Equinor presents Revenue from contracts with customers and Other revenue as a single caption, statement of income. Revenue from contracts with customers Revenue from contracts with customers is recognised upon satisfaction of the performance obligations services in each such contract. The revenue amounts that are recognised reflect the consideration to which entitled in exchange for those goods and services. Revenue from the sale of crude oil, merchandise is recognised when a customer obtains control of those products, which normally based on the contractual terms of the agreements. Each such sale normally represents a single performance natural gas, sales are completed over time in line with the delivery of the actual physical quantities. Sales and purchases of physical commodities are presented on a gross basis as Revenues from contracts Purchases [net of inventory variation] respectively in the Consolidated statement of income. When instruments or part of Equinor’s trading activities, they are settled and presented and gas volumes are always reflected gross as Revenue from contracts with customers. Revenues from the production of oil and gas in which Equinor shares an interest with volumes lifted and sold to customers during the period (the sales method). Where Equinor ownership interest, an accrual is recognised for the cost of the overlift. Where Equinor has lifted interest, costs are deferred for the underlift. Revenue is presented net of customs, excise taxes and royalties paid in-kind on petroleum products. Other revenue Items representing a form of revenue, or which are closely connected with revenue from contracts with Other revenue if they do not qualify as revenue from contracts with customers. These other revenue under certain production sharing agreements (PSAs) and the net impact of commodity trading and instruments connected with sales contracts or revenue-related risk management.
Transactions with the Norwegian State [text block]	Transactions with the Norwegian State Equinor markets and sells the Norwegian State's share of oil and gas production from the Norwegian State's participation in petroleum activities is organised through the SDFI. All purchases production are classified as purchases [net of inventory variation] and revenues from contracts with customers, Equinor sells, in its own name, but for the Norwegian State's account and risk, the State's production and related expenditures refunded by the Norwegian State are presented net in the Consolidated sales made in the name of Equinor subsidiaries are also presented net of the SDFI’s share in the but this activity is reflected gross in the Consolidated balance sheet. Accounting judgement related to transactions with the Norwegian State Whether to account for the transactions gross or net involves the use of significant Equinor has considered whether it controls the State originated crude oil volumes prior to onwards sales Equinor directs the use of the volumes, and although certain benefits from the sales subsequently purchases the crude oil volumes from the State and obtains substantially all the remaining benefits. concluded that it acts as principal in these sales. Regarding gas sales, Equinor concluded that ownership of the gas had not been transferred from Equinor has been granted the ability to direct the use of the volumes, all the benefits from the On that basis, Equinor is not considered the principal in the sale of the SDFI’s natural gas volumes
Employee benefits [text block]	Employee benefits Wages, salaries, bonuses, social security contributions, paid annual leave and sick leave are accrued in the period in associated services are rendered by employees of Equinor.
Research and development [text block]	Research and development Equinor undertakes research and development both on a funded basis for licence holders own risk. Equinor's own share of the licence holders' funding and the total costs of the unfunded capitalisation under the applicable IFRS requirements. Subsequent to initial recognition, reported at cost less accumulated amortisation and accumulated impairment losses.
Income tax [text block]	Income tax Income tax in the Consolidated statement of income comprises current and deferred tax expense. Consolidated statement of income except when it relates to items recognised in OCI. Current tax consists of the expected tax payable on the taxable income for the year and any years. Uncertain tax positions and potential tax exposures are analysed individually, and as tax disputes are mostly binary in nature, the most likely amount for probable liabilities to be paid (unpaid potential tax exposure amounts, be received (disputed tax positions for which payment has already been made) in each case is Deferred tax as appropriate. Interest income and interest expenses relating to tax issues are estimated which they are earned or incurred and are presented within Net financial items in the Consolidated on the NCS is recognised when the deduction is included in the current year tax return Deferred tax assets and liabilities are recognised for the future tax consequences attributable to amounts of existing assets and liabilities and their respective tax bases, and on unused tax losses to the initial recognition exemption. The amount of deferred tax is based on the expected manner carrying amount of assets and liabilities, using tax rates enacted or substantively enacted at the asset is recognised only to the extent that it is probable that future taxable income will utilised. In order for a deferred tax asset to be recognised based on future taxable income, account the existence of contracts, production of oil or gas in the near future based on volumes of proved in active markets, expected volatility of trading profits, expected foreign currency rate movements and similar facts When an asset retirement obligation or a lease contract is initially reflected in the accounts, a deferred deferred tax asset are recognised simultaneously and accounted for in line with other deferred tax with an amendment to IAS 12, reducing the scope of the initial recognition exemption, which Estimation uncertainty regarding income tax Every year Equinor incurs significant amounts of income taxes payable to various jurisdictions around the world significant changes to deferred tax assets and deferred tax liabilities. There may be uncertainties applicable tax laws and regulations regarding amounts in Equinor’s tax returns, regimes. For cases of uncertain tax treatments, it may take several years to complete the discussions to reach resolutions of the appropriate tax positions through litigation. The carrying values of income tax related assets and liabilities are based on Equinor's interpretations and relevant court decisions. The quality of these estimates, including the most likely outcomes dependent upon proper application of at times very complex sets of rules, the recognition of case of deferred tax assets, management's ability to project future earnings from activities that may apply loss carry against future income taxes. The Covid-19 pandemic has increased the uncertainty in determining key business assumptions used to assess the deferred tax assets through sufficient future taxable income before tax losses expire. Climate-related matters carbon-neutral energy-consumption globally could also influence Equinor’s future taxable carried forward and the recognition of deferred tax assets in certain tax jurisdictions
Oil and gas exploration, evaluation and development expenditures [text block]	Oil and gas exploration, evaluation and development expenditures Equinor uses the successful efforts method of accounting for oil and gas exploration costs. Expenditures to in oil and gas properties and to drill and equip exploratory wells are capitalised as exploration and intangible assets until the well is complete and the results have been evaluated, or there impairment. Exploration wells that discover potentially economic quantities of oil and natural gas assets during the evaluation phase of the discovery. This evaluation is normally finalised within one year after well completion. If, following the evaluation, the exploratory well has not found potentially commercial quantities of capitalised costs are evaluated for derecognition or tested for impairment. Geological and evaluation expenditures are expensed as incurred. Capitalised exploration and evaluation expenditures, including expenditures to acquire mineral interests related to offshore wells that find proved reserves, are transferred from Exploration expenditures and Acquisition costs - prospects (Intangible assets) to Property, plant and equipment at the time of sanctioning of the development project. The timing from evaluation of a discovery until a project is sanctioned could take several years depending on the existing infrastructure, of the area of discovery, whether a host government agreement is in place, the complexity of the project and the financial robustness of the project. For onshore wells where no sanction is required, the transfer and Acquisition cost – oil and gas prospects (Intangible assets) to Property, plant and equipment occurs at the time when a well is ready for production. For exploration and evaluation asset acquisitions (farm-in arrangements) in which Equinor has made arrangements of the selling partner's exploration and/or future development expenditures (carried interests), these expenditures Consolidated financial statements as and when the exploration and development work progresses. Equinor evaluation asset dispositions (farm-out arrangements) on a historical cost basis with no gain or loss recognition. A gain related to a post-tax-based disposition of assets on the NCS includes the release of tax liabilities previously recognised related to the assets in question. The resulting after-tax gain is recognised in full statement of income. Consideration from the sale of an undeveloped part of an onshore asset reduces the carrying amount consideration that exceeds the carrying amount of the asset, if any, is reflected in the Consolidated statement of income under Other income. Even exchanges (swaps) of exploration and evaluation assets with only immaterial cash considerations carrying amounts of the assets given up with no gain or loss recognition. Accounting judgement and estimation uncertainty regarding exploration activities Equinor capitalises the costs of drilling exploratory wells pending determination of whether reserves. Equinor also capitalises leasehold acquisition costs and signature bonuses paid to obtain access gas acreage. Judgements as to whether these expenditures should remain capitalised, be de-recognised or written may materially affect the carrying values of these assets and consequently, the operating income for the period.
Property, plant and equipment [text block]	Property, plant and equipment Property, plant and equipment is reflected at cost, less accumulated depreciation and accumulated impairment losses. The initial cost of an asset comprises its purchase price or construction cost, any costs directly attributable initial estimate of an asset retirement obligation, if any, exploration costs transferred from intangible assets and, for qualifying assets, borrowing costs. Proceeds from production ahead of a project’s final approval are regarded as ‘early production’ revenue rather than as a reduction of acquisition cost. Contingent consideration included in similar assets is initially measured at its fair value, with later changes in fair value other than the book value of the asset or group of assets, unless the asset is impaired. Property, plant and equipment include costs relating to expenditures incurred under the terms of PSAs in certain countries, and which qualify for recognition owned entities in the respective countries, however, normally hold the legal title to such PSA-based property, plant and equipment. Exchanges of assets are measured at fair value, primarily of the asset given up, unless the fair value the asset given up is measurable with sufficient reliability. Expenditure on major maintenance refits or repairs comprises the cost of replacement assets overhaul costs. Where an asset or part of an asset is replaced and it is probable that future economic item will flow to Equinor, the expenditure is capitalised. Inspection and overhaul costs, associated with regularly scheduled major maintenance programmes planned and carried out at recurring intervals exceeding one year, are capitalised and amortised over the period to the next scheduled inspection and overhaul. All other maintenance costs are expensed Capitalised exploration and evaluation expenditures, development expenditure on the construction, installation infrastructure facilities such as platforms, pipelines and the drilling of production wells, and field-dedicated transport and gas are capitalised as Producing oil and gas properties within Property, plant and equipment. Such capitalised costs, when designed for significantly larger volumes than the reserves from already developed and producing unit of production method based on proved reserves expected to be recovered from the Depreciation of production wells uses the unit of production method based on proved developed costs of proved properties are depreciated using the unit of production method based on total proved circumstances where the use of proved reserves fails to provide an appropriate basis reflecting the economic benefits are expected to be consumed, a more appropriate reserve estimate is used. Depreciation transport systems used by several fields is calculated on the basis of their estimated useful lives, method. Each part of an item of property, plant and equipment with a cost that is significant in relation to the total cost of the item is depreciated separately. For exploration and production assets, Equinor has established separate depreciation categories which as a minimum distinguish between platforms, pipelines and wells. The estimated useful lives of property, plant and equipment are reviewed on an annual basis, and changes in useful lives are accounted for prospectively. An item of property, plant and equipment is de-recognised upon disposal or when no future economic benefits are expected to arise from the continued use of the asset. Any gain or loss arising as the difference between the net disposal proceeds and the carrying amount of the item) is included expenses, respectively, in the period the item is derecognised. Monetary or non-monetary grants from governments, when related to property, plant and equipment and considered reasonably certain, are recognised in the Consolidated balance sheet as a deduction to the carrying recognised in the Consolidated statement of income over the life of the depreciable asset Estimation uncertainty regarding determining oil and gas reserves Reserves estimates are complex and based on a high degree of professional judgement involving assessments of in-place hydrocarbon volumes, the production, historical recovery and processing operating capacity. Recoverable oil and gas quantities are always uncertain. The reliability of these estimates at any point in time depends on both the quality and availability of the technical and economic data and hydrocarbons. Reserves quantities are, by definition, discovered, remaining, recoverable and economic. Estimation uncertainty; Proved oil and gas reserves Proved oil and gas reserves may impact the carrying amounts of oil and gas producing assets, instance as a result of changes in prices, will impact the unit of production rates used for depreciation gas reserves are those quantities of oil and gas, which, by analysis of geoscience and reasonable certainty to be economically producible from a given date forward, from known conditions, operating methods and government regulations. Unless evidence indicates that renewal proved reserves only reflect the period before the contracts providing the right to operate expire. proved reserves estimates are included only where there is a significant commitment to project relevant governmental and regulatory approvals have been secured or are reasonably certain to Proved reserves are divided into proved developed and proved undeveloped reserves. Proved developed recovered through existing wells with existing equipment and operating methods, or where the relatively minor compared to the cost of a new well. Proved undeveloped reserves are to acreage, or from existing wells where a relatively major capital expenditure is required for be classified as having proved undeveloped reserves if a development plan is in place indicating within five years, unless specific circumstances justify a longer time horizon. Specific circumstances are for large up-front investments in offshore infrastructure, such as many fields on the NCS, where drilling of wells for much longer than five years. For unconventional reservoirs where continued drilling such as the US onshore assets, the proved reserves are always limited to proved well locations scheduled years. Proved oil and gas reserves have been estimated by internal qualified professionals on the governed by the oil and gas rules and disclosure requirements in the U.S. Securities and Exchange K and S-X, and the Financial Accounting Standards Board (FASB) requirements for supplemental oil and gas disclosures. The estimates have been based on a 12-month average product price and on existing economic conditions required, and recovery of the estimated quantities have a high degree of certainty (at least party has evaluated Equinor's proved reserves estimates, and the results of this evaluation do not estimates. Estimation uncertainty; Expected oil and gas reserves Changes in the expected oil and gas reserves, for instance as a result of changes in asset retirement obligations, as a consequence of timing of the removal activities. It may also impact and gas assets, possibly also affecting impairment testing and the recognition of deferred tax assets. Expected are the estimated remaining, commercially recoverable quantities, based on Equinor's judgement projects in operation or decided for development. Recoverable oil and gas quantities are always guidelines, expected reserves are defined as the ‘forward looking mean reserves’ when based on some cases, a deterministic prediction method is used, in which case the expected reserves estimate. Expected reserves are therefore typically larger than proved reserves as defined by the estimates with at least a 90% probability of recovery when a probabilistic approach is used. estimated by internal qualified professionals on the basis of industry standards and classified in accordance with resource classification system issued by the Norwegian Petroleum Directorate.
Assets classified as held for sale [text block]	Assets classified as held for sale Non-current assets are classified separately as held for sale in the Consolidated balance sheet recovered through a sales transaction rather than through continuing use. This condition is met only when which is when the asset is available for immediate sale in its present condition, and management should be expected to qualify for recognition as a completed sale within one year from associated with the assets classified as held for sale and expected to be included as part also classified separately. Once classified as held for sale, property, plant and equipment and intangible assets are not subject to depreciation or amortisation. The net assets and liabilities of a disposal group classified as held for their carrying amount and fair value less costs to sell.
Leases [text block]	Leases A lease is defined as a contract that conveys the right to control the use of an identified asset for consideration. As a lessee, each contract that meets the definition of a lease is recognised in the date at which the underlying asset is made available for Equinor, the present value of future lease payments is recognised as a lease liability. A corresponding right-of-use (RoU) asset is recognised, including also lease payments and direct costs incurred at or before the commencement date. Future lease payments are reflected as interest expense are depreciated over the shorter of each contract’s term and the assets’ useful life. The present value of fixed lease payments (or variable lease payments, if the payment depends using the interest rate implicit in the lease, or if that rate cannot be readily determined, Equinor’s non-cancellable period Equinor has the right to use the underlying asset. Extension considered reasonably certain to be exercised. Short term leases (12 months or less) and leases of low value assets are not reflected in the Consolidated expensed or (if appropriate) capitalised as incurred, depending on the activity in which the leased Many of Equinor’s lease contracts, such as rig and vessel leases, involve several additional personnel cost, maintenance, drilling related activities, and other items. For a number of these represent a not inconsiderable portion of the total contract value. Non-lease components within lease contracts separately for all underlying classes of assets and reflected in the relevant expense category or (if incurred, depending on the activity involved. Where all partners in a licence are considered to share the primary responsibility for lease payments under lease liability and RoU asset will be recognised net by Equinor, on the basis of Equinor’s participation interest Equinor is considered to have the primary responsibility for the full external lease payments, (100%). Equinor derecognises a portion of the RoU asset equal to the non-operator’s corresponding financial lease receivable, if a financial sublease is considered to exist between sublease will typically exist where Equinor enters into a contract in its own name, has the payments, the underlying asset will only be used on one specific licence, and the costs and risks carried by that specific licence. Accounting judgement regarding leases In the oil and gas industry, where activity frequently is carried out through joint arrangements or similar arrangements, the application of IFRS 16 requires evaluations of whether the joint arrangement or its operator is the lessee consequently whether such contracts should be reflected gross (100%) in the operator’s joint operation partner’s proportionate share of the lease. In many cases where an operator is the sole signatory to a lease contract of an asset to operation, the operator does so implicitly or explicitly on behalf of the joint arrangement. In certain Equinor as this includes the Norwegian continental shelf (NCS), the concessions granted by the an obligation for the operator to enter into necessary agreements in the name of the joint operations As is the customary norm in upstream activities operated through joint arrangements, the operator will lessor, and subsequently re-bill the partners for their share of the lease costs. In each such instance, it is necessary to determine whether the operator is the sole lessee in the external lease arrangement, and if so, whether sub-leases, or whether it is in fact the joint arrangement which is the lessee, with each share of the lease. Depending on facts and circumstances in each case, the conclusions legal jurisdictions.
Intangible assets including goodwill [text block]	Intangible assets including goodwill Intangible assets are stated at cost, less accumulated amortisation and accumulated impairment acquisition cost for oil and gas prospects, expenditures on the exploration for and and other intangible assets. Intangible assets relating to expenditures on the exploration for and evaluation of oil and natural When the decision to develop a particular area is made, its intangible exploration and evaluation plant and equipment. Goodwill is initially measured at the excess of the aggregate of the consideration transferred noncontrolling interest over the fair value of the identifiable assets acquired and liabilities assumed in acquisition date. Goodwill acquired is allocated to each cash generating unit (CGU), or group combination’s synergies. Following initial recognition, goodwill is measured at cost less any accumulated impairment losses. In acquisitions made on a post-tax basis according to the rules on the NCS, a provision for deferred based on the difference between the acquisition cost and the transferred tax depreciation basis. The offsetting entry to such deferred tax amounts is reflected as goodwill, which is allocated to the CGU or group of CGUs has been computed. Other intangible assets with a finite useful life, are depreciated over their useful life using the straight-line
Financial assets [text block]	Financial assets Financial assets are initially recognised at fair value when Equinor becomes a party to the contractual provisions additional information on fair value methods, refer to the Measurement of fair values section below. The subsequent measurement of the financial assets depends on which category they have been classified into at inception. At initial recognition, Equinor classifies its financial assets into the following three categories: Financial at fair value through profit or loss, and at fair value through other comprehensive income based on an evaluation of terms and the business model applied. Certain long-term investments in other entities, which do consolidation, are included as at fair value through profit or loss. Cash and cash equivalents include cash in hand, current balances with banks and similar institutions, investments that are readily convertible to known amounts of cash, are subject to an insignificant have a maturity of three months or less from the acquisition date. Short-term highly liquid investments with 3 months are classified as current financial investments. Contractually mandatory deposits in escrow restricted cash if the deposits are provided as part of the Group’s operating activities and therefore is deemed of meeting short-term cash commitments, and the deposits can be released from the escrow and cash equivalents and current financial investment are accounted for at amortised cost or Trade receivables are carried at the original invoice amount less a provision for doubtful receivables which represent expected losses computed on a probability-weighted basis. Equinor’s financial asset impairment losses are measured and recognised based A part of Equinor's financial investments is managed together as an investment portfolio is held in order to comply with specific regulations for capital retention. The investment portfolio value basis in accordance with an investment strategy and is accounted for at fair value through profit or loss. Financial assets are presented as current if they contractually will expire or otherwise are expected to be after the balance sheet date, or if they are held for the purpose of being traded. Financial separately in the Consolidated balance sheet, unless Equinor has both a legal right and a demonstrable balances payable to and receivable from the same counterparty, in which case they are shown net in the Consolidated balance sheet. Financial assets are de-recognised when rights to cash flows and risks and rewards of ownership transaction or the contractual rights to the cash flows expire, are redeemed, or cancelled. Gains settlement or cancellation of financial assets are recognised either in interest income and other financial finance expenses within Net financial items.
Inventories [text block]	Inventories Commodity inventories are stated at the lower of cost and net realisable value. Cost is comprises direct purchase costs, cost of production, transportation and manufacturing expenses. parts are reflected according to the weighted average method.
Impairment [text block]	Impairment of property, plant and equipment, right-of-use assets and intangible assets including goodwill Equinor assesses individual assets or groups of assets for impairment whenever events or changes in carrying value of an asset may not be recoverable. Assets are grouped into cash generating units (CGUs) identifiable groups of assets that generate cash inflows that are largely independent of the Normally, separate CGUs are individual oil and gas fields or plants. Each unconventional asset play is considered a single CGU when no cash inflows from parts of the play can be reliably identified as being largely independent play. In impairment evaluations, the carrying amounts of CGUs are determined on a basis consistent with that of the recoverable amount. In Equinor's line of business, judgement is involved in determining what constitutes infrastructure solutions, markets, product pricing, management actions and other factors may over time lead as the disaggregation of one original CGU into several. In assessing whether a write-down of the carrying amount of a potentially impaired asset is required, compared to the recoverable amount. The recoverable amount of an asset is the higher of its value in use. Fair value less cost of disposal is determined based on comparable recent arm’s length market transactions Equinor’s estimate of the price that would be received for the asset in value estimates are mainly based on discounted cash flow models, using assumed market participants’ assumptions, reflect market multiples observed from comparable market transactions or independent third-party valuations. determined using a discounted cash flow model. The estimated future cash flows applied in establishing reasonable and supportable assumptions and represent management's best estimates of the exist over the remaining useful life of the assets, as set down in Equinor's most recently approved long-term and economic conditions in establishing the long-term forecasts are reviewed by management annually. See note 11 For assets and CGUs with an expected useful life or timeline for production of expected beyond five years, including planned onshore production from shale assets with a long development and forecasts reflect expected production volumes, and the related cash flows include project relevant period. Such estimates are established based on Equinor's principles and assumptions and are In performing a value-in-use-based impairment test, the estimated future cash flows are adjusted discounted using a real post-tax discount rate which is based on Equinor's post-tax weighted average cost risk specific to a project is included as a monetary adjustment to the projects’ cash flow. Equinor regards country risk primarily as an unsystematic risk. The cash flow is adjusted for risk that influence the expected cash project itself. The use of post-tax discount rates in determining value in use does not result in a materially the need for, or the amount of, impairment that would be required if pre-tax discount rates had been used. Unproved oil and gas properties are assessed for impairment when facts and circumstances asset or CGU to which the unproved properties belong may exceed its recoverable amount, wells that have found reserves, but where classification of those reserves as proved depends on can be justified or where the economic viability of that major capital expenditure depends on the exploration work, will remain capitalised during the evaluation phase for the exploratory finds. for impairment evaluation of the well if no development decision is planned for in the near future drilling in the licence. An assessment is made at each reporting date as to whether there is any indication that no longer be relevant or may have decreased. If such an indication exists, the recoverable recognised impairment loss is reversed only if there has been a change in the amount since the last impairment loss was recognised. If that is the case, the carrying amount recoverable amount. That increased amount cannot exceed the carrying amount that would have depreciation, had no impairment loss been recognised for the asset in prior years. Impairment losses and reversals of impairment losses are presented in the Consolidated statement expenses or Depreciation, amortisation and net impairment losses, on the basis of their nature as exploration assets) or development and producing assets (property, plant and equipment and other intangible assets), respectively. Goodwill is reviewed for impairment annually or more frequently if events or changes in circumstances may be impaired. Impairment is determined by assessing the recoverable amount of the CGU, relates. Where the recoverable amount of the CGU, or group of units, is less than the recognised. When impairment testing goodwill originally recognised as an offsetting item to the computed deferred tax post-tax transaction on the NCS, the remaining amount of the deferred tax provision will factor recognised, impairments of goodwill are not reversed in future periods. Estimation uncertainty regarding impairment Changes in the circumstances or expectations of future performance of an individual asset may impaired, requiring its carrying amount to be written down to its recoverable amount. Impairments impairment are no longer present. Evaluating whether an asset is impaired or if an impairment degree of judgement and may to a large extent depend upon the selection of key assumptions about The key assumptions used will bear the risk of change based on the inherent volatile nature of macro-economic commodity prices or discount rate and uncertainty in asset specific factors such as reserve estimates impacting the production profile or activity levels for our oil and natural gas properties. Changes in foreign will also affect value-in-use, especially for NCS-assets, where the functional currency is NOK. When estimating the recoverable amount, the expected cash flow approach is applied to reflect uncertainties in timing and amounts inherent in the estimated future cash flows, including climate-related matters affecting those assumptions. For example, climate-related matters (see also Note 3 Consequences of initiatives to limit climate changes) are expected to affecting not only supply, demand and commodity prices, but also technology-changes, increased emission-related levies and other matters with mainly mid-term and long-term effects. These effects have been factored into the price assumptions used for future cash flows using probability-weighted scenario analyses. Unproved oil and gas properties are assessed for impairment when facts and circumstances relevant asset or CGU may exceed its recoverable amount, and at least annually. If, following evaluation, an exploratory well has not found proved reserves, the previously capitalised costs are tested for impairment. Subsequent to it will be considered a trigger for impairment testing of a well if no development decision is firm plan for future drilling in the licence. Impairment of unsuccessful wells is reversed, as applicable, to impairment are no longer present. Where recoverable amounts are based on estimated future cash flows, reflecting Equinor’s, sources’ assumptions about the future and discounted to their present value, the estimates involve complexity. Impairment testing requires long-term assumptions to be made concerning a number of economic factors such as future foreign currency exchange rates and future output, discount rates, impact of the timing country risk among others, in order to establish relevant future cash flows. Long-term assumptions made at a group level, and there is a high degree of reasoned judgement involved in other relevant factors such as forward price curves, in estimating production outputs and in an asset.
Financial liabilities [text block]	Financial liabilities Financial liabilities are initially recognised at fair value when Equinor becomes a party to subsequent measurement of financial liabilities depends on which category they have been for Equinor are either financial liabilities at fair value through profit or loss or financial liabilities measured effective interest method. The latter applies to Equinor's non-current bank loans and bonds. Financial liabilities are presented as current if the liability is expected to be settled as liability is due to be settled within 12 months after the balance sheet date, Equinor liability more than 12 months after the balance sheet date, or if the liabilities are held for the liabilities are de-recognised when the contractual obligations are settled, or if they expire, are losses arising on the repurchase, settlement or cancellation of liabilities are recognised either in Interest income items or in Interest and other finance expenses within Net financial items.
Share buyback policy [Text Block]	Share buy-backs Where Equinor has either acquired own shares under a share buy-back programme party for Equinor shares to be acquired in the market, such shares are reflected remaining outstanding part of an irrevocable order to acquire shares is accrued for and classified as Trade, other payables and provisions.
Derivative financial instruments [text block]	Derivative financial instruments Equinor uses derivative financial instruments to manage certain exposures to fluctuations in foreign rates and commodity prices. Such derivative financial instruments are initially recognised at derivative contract is entered into and are subsequently re-measured at fair value through profit based derivative financial instruments is recognised in the Consolidated statement of income under derivative instruments are related to sales contracts or revenue-related risk management for all significant purposes. The impact other derivative financial instruments is reflected under Net financial items. Derivatives are carried as assets when the fair value is positive and as liabilities when liabilities expected to be recovered, or with the legal right to be settled more than 12 months classified as non-current. Derivative financial instruments held for the purpose of being traded are current. Contracts to buy or sell a non-financial item that can be settled net in cash or another instruments, as if the contracts were financial instruments, are accounted for as financial entered into and continue to be held for the purpose of the receipt or delivery of a non-financial item expected purchase, sale or usage requirements, also referred to as own-use, are not accounted for sales and purchases of physical commodity volumes are reflected in the Consolidated statement contracts with customers and Purchases [net of inventory variation], respectively. This is applicable to a significant number of contracts for the purchase or sale of crude oil and natural gas, which are recognised upon delivery. For contracts to sell a non-financial item that can be settled net in cash, but which ultimately qualifying as own use prior to settlement, the changes in fair value prior to settlement is included derivatives. The resulting impact upon physical settlement is shown separately and included in Other deliveries made by Equinor through such contracts are included in Revenue from contracts with Derivatives embedded in host contracts which are not financial assets within the scope of IFRS derivatives and are reflected at fair value with subsequent changes through profit and characteristics are not closely related to those of the host contracts, and the host contracts are not carried an active market for a commodity or other non-financial item referenced in a purchase or sale contract, instance, be considered to be closely related to the host purchase or sales contract in question. A price formula with indexation to other markets or products will however result Where there is no active market for the commodity or other non-financial item in question, Equinor such a price related embedded derivative to be closely related to the host contract if commonly used by other market participants. This applies to certain long-term natural gas sales
Pension Liabilities [text block]	Pension liabilities Equinor has pension plans for employees that either provide a defined pension benefit upon retirement or a defined contributions and related returns. A portion of the contributions are provided increases with a promised notional return, set equal to the actual return of assets invested through plan. For defined benefit plans, the benefit to be received by employees generally service, retirement date and future salary levels. Equinor's proportionate share of multi-employer defined benefit plans is recognised as liabilities in the Consolidated the extent that sufficient information is available, and a reliable estimate of the obligation can be made. Equinor's net obligation in respect of defined benefit pension plans is calculated separately for each future benefit that employees have earned in return for their services in the current and prior periods. That determine its present value, and the fair value of any plan assets is deducted. The discount reflecting the maturity dates approximating the terms of Equinor's obligations. The discount rate for the main obligations has been established on the basis of Norwegian mortgage covered bonds, which are considered bonds. The cost of pension benefit plans is expensed over the period that the employees receive benefits. The calculation is performed by an external actuary. The net interest related to defined benefit plans is calculated by applying the discount rate to obligation and opening present value of the plan assets, adjusted for material changes during the year. The resulting net interest element is presented in the Consolidated statement of income within Net financial items. The income and actual return is recognised in the Consolidated statement of comprehensive income. Past service cost is recognised when a plan amendment (the introduction or withdrawal curtailment (a significant reduction by the entity in the number of employees covered by a restructuring costs or termination benefits. The obligation and related plan assets are assumptions, and the gain or loss is recognised in the Consolidated statement of income. Actuarial gains and losses are recognised in full in the Consolidated statement of comprehensive occur, while actuarial gains and losses related to provision for termination benefits are recognised in the Consolidated statement of income in the period in which they occur. Due to the parent company Equinor ASA's functional currency being USD, the part of Equinor's pension obligations will be payable in a foreign currency (i.e. NOK). As related to the parent company's pension obligations include the impact of exchange rate fluctuations. Contributions to defined contribution schemes are recognised in the Consolidated statement of income in contribution amounts are earned by the employees. Notional contribution plans, reported in the parent company Equinor ASA, are recognised as Pension the notional contributions and promised return at reporting date. Notional contributions are recognised of income as periodic pension cost, while changes in fair value of notional assets are reflected income under Net financial items. Periodic pension cost is accumulated in cost pools and allocated to business areas and Equinor on an hours’ incurred basis and recognised in the statement of income based on the
Onerous contracts [text block]	Onerous contracts Equinor recognises as provisions the net obligation under contracts defined as onerous. Contracts unavoidable cost of meeting the obligations under the contract exceeds the economic benefits the contract. The provision for onerous contracts comprises the costs that relate directly allocation of other costs that relate directly to fulfilling the contracts. A contract which forms an integral whose assets are dedicated to that contract, and for which the economic benefits cannot be reliably is included in impairment considerations for the applicable CGU.
Asset retirement obligations (ARO) [text block]	Asset retirement obligations (ARO) Provisions for ARO costs are recognised when Equinor has an obligation (legal or constructive) an item of property, plant and equipment and to restore the site on which it is located, and when a reliable estimate of that liability can be made. The amount recognised is the present value of the estimated future expenditures determined conditions and requirements. The cost is estimated based on current regulations and technology, considering relevant risks and uncertainties. The discount rate used in the calculation of the ARO is a risk-free rate based on the horizon of the underlying cash flows. To better represent the risks specific to the ARO liability, and as described in a previous paragraph regarding changes in accounting policies, Equinor no longer includes a credit premium Normally an obligation arises for a new facility, such as an oil and natural gas production or transportation facility, upon construction or installation. An obligation may also arise during the period of operation of a facility through a change decision to terminate operations or be based on commitments associated with Equinor's ongoing where removal obligations rest with the volume shippers. The provisions are classified under Provisions sheet. When a provision for ARO cost is recognised, a corresponding amount is recognised to increase equipment and is subsequently depreciated as part of the costs of the facility or item of property, plant and equipment. Any change in the present value of the estimated expenditure is reflected as an adjustment to the and equipment. When a decrease in the ARO provision related to a producing asset exceeds the excess is recognised as a reduction of Depreciation, amortisation and net impairment losses in the When an asset has reached the end of its useful life, all subsequent changes to the ARO Operating expenses in the Consolidated statement of income. Removal provisions associated with Equinor's volumes through third party transport systems are expensed as incurred. Estimation uncertainty regarding asset retirement obligations Establishing the appropriate estimates for such obligations are based on historical knowledge combined with technological developments and involve the application of judgement and involve an inherent of decommissioning and removal activities require revisions due to changes in current regulations relevant risks and uncertainties. Most of the removal activities are many years into the future, and the are constantly changing. The speed of the transition to new renewable energy may also influence hence the timing of the removal activities. The estimates include assumptions of norms, rates and considerably depending on the assumed removal complexity. Moreover, changes in the discount rate and foreign currency exchange rates may impact the estimates significantly. As a result, the initial recognition of the liability and the capitalised cost associated with decommissioning and removal obligations, and the subsequent adjustment of these balance sheet items, involve significant judgement.
Measurement of fair values [text block]	Measurement of fair values Quoted prices in active markets represent the best evidence of fair value and are used by Equinor assets and liabilities to the extent possible. Financial instruments quoted in active markets will with quoted market prices obtained from the relevant exchanges or clearing houses. The fair financial liabilities and derivative instruments are determined by reference to mid-market prices, at the balance sheet date. Where there is no active market, fair value is determined using valuation techniques. These include transactions, reference to other instruments that are substantially the same, discounted cash flow analysis, related internal assumptions. In the valuation techniques, Equinor also takes into consideration risk. This is either reflected in the discount rate used or through direct adjustments to the calculated Equinor reflects elements of long-term physical delivery commodity contracts at fair value, such fair value estimates to possible are based on quoted forward prices in the market and underlying indexes in the prices and margins where observable market prices are not available. Similarly, the fair values of interest and currency swaps are estimated based on relevant quotes from active markets, quotes of comparable instruments, and techniques. Estimation uncertainty regarding the Covid-19 pandemic During 2020, the Covid-19 pandemic slowed economic growth and had dramatic consequences mobility fuels, resulting in a collapse in commodity prices in the first half of 2020. Commodity half of 2020 and have since the first quarter of 2021 surpassed pre-pandemic levels. When setting supply, demand and commodity prices, management factored in the effects of global roll-out of vaccines during 2021 and 2022. Virus mutation is still causing new waves of lockdown and other restrictions, but the Omicron variant seems less governments ease restrictions as former variants are being outcompeted. Even though we the near future, there is always inherent uncertainties and a risk of new virus flare-ups for as long The outlook is still somewhat uncertain and dominated by downside risks such as virus infection continued global vaccination and the scope of monetary and fiscal governmental stimuli will still affect the economy in the As such, the full resulting operational and economic impact for Equinor from the pandemic Apart from the financial impact, Equinor has only experienced immaterial effects on production from assets in operation, actions taken to maintain and secure safe production during the pandemic. Minor virus occurred, but effective measures such as isolation and quarantines combined with social distancing requirements have prevented production shutdown, and operations have not been significantly impacted. For projects under development, the Covid-19 pandemic has impacted progress due to personnel limitations facilities / yards due to infection control measures and associated travel restrictions for migrant workforce. degree still unpredictable and may have additional consequences for the progress and costs

Segments (Tables)

Segments (Tables)	12 Months Ended
	Dec. 31, 2021
Disclosure of operating segments [abstract]
Operating segments data [text block]	Full year 2021 E&P Norway E&P International E&P USA MMP REN Other Eliminations Total (in USD million) Revenues third party, other revenue and other income 269 1,113 377 87,025 1,394 485 0 90,665 Revenues inter-segment 38,972 4,230 3,771 321 0 5 (47,300) 0 Net income/(loss) from equity accounted investments 0 214 0 22 16 7 0 259 Total revenues and other income 39,241 5,558 4,149 87,368 1,411 497 (47,300) 90,924 Purchases [net of inventory variation] 0 (58) 0 (80,873) 0 (1) 45,773 (35,160) Operating, selling, general and administrative expenses (3,729) (1,466) (1,076) (4,276) (163) 264 1,066 (9,378) Depreciation, amortisation and net impairment losses (4,678) (3,257) (1,733) (1,079) (3) (970) 0 (11,719) Exploration expenses (363) (451) (190) 0 0 0 0 (1,004) Total operating expenses (8,770) (5,232) (2,999) (86,227) (166) (707) 46,839 (57,261) Net operating income/(loss) 30,471 326 1,150 1,141 1,245 (210) (461) 33,663 Additions to PP&E, intangibles and equity accounted investments 5,101 1,828 690 221 455 212 0 8,506 Balance sheet information Equity accounted investments 3 1,417 0 113 1,108 45 0 2,686 Non-current segment assets 35,301 15,358 11,406 3,019 154 3,288 0 68,527 Non-current assets not allocated to segments 13,406 Total non-current assets 84,618 Full year 2020 E&P Norway E&P International E&P USA MMP REN 1) Other 1) Eliminations Total (in USD million) Revenues third party, other revenue and other income 91 451 368 44,605 18 232 0 45,765 Revenues inter-segment 11,804 3,183 2,247 309 0 4 (17,547) 0 Net income/(loss) from equity accounted investments 0 (146) 0 31 163 5 0 53 Total revenues and other income 11,895 3,489 2,615 44,945 181 241 (17,547) 45,818 Purchases [net of inventory variation] 0 (72) 0 (38,072) 0 1 17,157 (20,986) Operating, selling, general and administrative expenses (2,829) (1,439) (1,313) (5,060) (215) 634 685 (9,537) Depreciation, amortisation and net impairment losses (5,546) (3,471) (3,824) (1,453) (1) (939) 0 (15,235) Exploration expenses (423) (2,071) (990) 0 0 1 0 (3,483) Total operating expenses (8,798) (7,054) (6,127) (44,586) (216) (304) 17,842 (49,241) Net operating income/(loss) 3,097 (3,565) (3,512) 359 (35) (63) 296 (3,423) Additions to PP&E, intangibles and equity accounted investments 4,851 2,609 1,068 190 31 1,013 0 9,762 Balance sheet information Equity accounted investments 3 1,125 0 92 1,017 25 0 2,262 Non-current segment assets 2) 37,733 17,835 12,586 4,368 3 4,132 0 76,657 Non-current assets not allocated to segments 13,704 Total non-current assets 92,623 1) Reclassified. 2) Restated. For more information, see note 21 Full year 2019 E&P Norway E&P International E&P USA MMP REN 1) Other 1) Eliminations Total (in USD million) Revenues third party, other revenue and other income 1,048 1,685 441 60,491 258 269 0 64,194 Revenues inter-segment 17,769 4,376 3,792 439 0 4 (26,379) 0 Net income/(loss) from equity accounted investments 15 24 6 25 95 (1) 0 164 Total revenues and other income 18,832 6,085 4,239 60,955 353 271 (26,379) 64,357 Purchases [net of inventory variation] (1) (34) 0 (54,454) 0 (1) 24,958 (29,532) Operating, selling, general and administrative expenses (3,284) (1,684) (1,668) (4,897) (192) 465 793 (10,469) Depreciation, amortisation and net impairment losses (5,439) (2,228) (4,133) (600) (1) (803) 0 (13,204) Exploration expenses (478) (668) (709) 0 0 0 0 (1,854) Total operating expenses (9,201) (4,614) (6,510) (59,951) (193) (339) 25,750 (55,058) Net operating income/(loss) 9,631 1,471 (2,271) 1,004 160 (68) (629) 9,299 Additions to PP&E, intangibles and equity accounted investments 7,316 2,851 3,004 788 175 648 0 14,782 Balance sheet information Equity accounted investments 3 321 0 90 1,003 25 0 1,442 Non-current segment assets 2) 34,938 21,161 16,929 5,248 187 4,026 0 82,489 Non-current assets not allocated to segments 11,152 Total non-current assets 95,083 1) Reclassified. 2) Restated. For more information, see note 21 Provisions
Non-current assets by country [text block]	Non-current assets by country At 31 December (in USD million) 2021 2020 2) Norway 40,564 44,311 USA 12,323 13,383 Brazil 8,751 8,359 UK 2,096 4,491 Azerbaijan 1,654 1,708 Canada 1,403 1,584 Russia 1,235 973 Angola 948 883 Algeria 708 808 Denmark 536 953 Other 996 1,465 Total non-current assets 1) 71,213 78,919
Revenues from contracts with customers [text block]	Revenues from contracts with customers and (in USD million) 2021 2020 2019 Crude oil 38,307 24,509 33,505 Natural gas 28,050 7,213 11,281 24,900 5,839 9,366 1,783 1,010 1,359 1,368 363 556 Refined products 11,473 6,534 10,652 Natural gas liquids 8,490 5,069 5,807 Transportation 921 1,083 967 Other sales 1,006 681 445 Total revenues from contracts with customers 88,247 45,088 62,657 Taxes paid in-kind 345 93 344 Physically settled commodity derivatives (1,075) 209 (1,086) Gain/(loss) on commodity derivatives 951 108 732 Other revenues 276 256 265 Total other revenues 497 665 254 Revenues 88,744 45,753 62,911

Financial risk and capital ma_2

Financial risk and capital management (Tables)	12 Months Ended
	Dec. 31, 2021
Financial risk and capital management [Abstract]
Maturity profile, based on undiscounted contractual cash flows	At 31 December 2021 2020 (in USD million) Non-derivative financial liabilities Lease liabilities Derivative financial liabilities Non-derivative financial liabilities Lease liabilities Derivative financial liabilities Year 1 18,841 1,183 175 13,388 1,220 1,262 Year 2 and 3 6,684 1,262 211 5,528 1,598 75 Year 4 and 5 6,140 656 318 6,489 772 264 Year 6 to 10 10,636 642 588 12,401 752 269 After 10 years 12,849 158 187 14,614 162 425 Total specified 55,150 3,901 1,479 52,421 4,504 2,294
Credit risk exposure, internal credit grades [text block]	(in USD million) Non-current financial receivables Trade and other receivables Non-current derivative financial instruments Current derivative financial instruments At 31 December 2021 Investment grade, rated A or above 452 3,637 1,103 2,902 Other investment grade 18 8,930 0 1,524 Non-investment grade or not rated 238 4,624 162 705 Total financial assets 708 17,191 1,265 5,131 At 31 December 2020 Investment grade, rated A or above 211 1,954 1,850 465 Other investment grade 24 2,288 478 287 Non-investment grade or not rated 262 3,176 148 134 Total financial assets 497 7,418 2,476 886
Disclosure of Capital Management	At 31 December (in USD million) 2021 2020 Net interest-bearing debt adjusted, including lease 3,236 20,121 Net interest-bearing debt adjusted (ND2) (326) 15,716 Capital employed adjusted, including lease liabilities 42,259 54,012 Capital employed adjusted (CE2) 38,697 49,608 Net debt to capital employed adjusted, including 7.7% 37.3% Net debt to capital employed adjusted (ND2/CE2) (0.8%) 31.7%

Remuneration (Tables)

Remuneration (Tables)	12 Months Ended
	Dec. 31, 2021
Renumeration [abstract]
Schedule Of Renumeration Explanatory [Table Text Block]	Full year (in USD million, except average number of employees) 2021 2020 2019 Salaries 1) 2,962 2,625 2,766 Pension costs 2) 488 432 446 Payroll tax 414 368 413 Other compensations and social costs 288 283 330 Total payroll costs 4,152 3,707 3,955 Average number of employees 3) 21,400 21,700 21,400 Salaries include bonuses, severance packages and expatriate costs in addition to base pay. 2) 3) 3 % for 2021, 2 % for 2020 and 4 % for 2019.
Remuneration to members of the BoD and the CEC [text block]	Full year (in USD thousand) 1) 2021 2020 2019 Current employee benefits 12,229 9,012 10,958 Post-employment benefits 420 589 661 Other non-current benefits 17 14 18 Share-based payment benefits 83 125 147 Total benefits 12,749 9,740 11,782 1) All figures in the table are presented on accrual basis.

Other expenses (Tables)

Other expenses (Tables)	12 Months Ended
	Dec. 31, 2021
Other Expense [Abstract]
Auditor's remuneration [text block]	Auditor's remuneration Full year (in USD million, excluding VAT) 2021 2020 2019 Audit fee Ernst & Young (principal accountant from 2019) 14.4 10.7 4.7 Audit fee KPMG (principal accountant 2018) - 2.8 Audit related fee Ernst & Young (principal accountant from 2019) 1.1 1.0 0.5 Audit related fee KPMG (principal accountant 2018) - 1.2 Tax fee Ernst & Young - - 0.2 Tax fee KPMG (principal accountant 2018) - - Other service fee Ernst & Young (principal accountant from 2019) - - 0.9 Other service fee KPMG (principal accountant 2018) - - Total remuneration 15.5 11.7 10.3

Financial items (Tables)

Financial items (Tables)	12 Months Ended
	Dec. 31, 2021
Finance Income Expense [Abstract]
Schedule of Finance items [text block]	Full year (in USD million) 2021 2020 2019 Foreign currency exchange gains/(losses) derivative 870 (1,288) 132 Other foreign currency exchange gains/(losses) (823) 642 92 Net foreign currency exchange gains/(losses) 47 (646) 224 Dividends received 39 44 75 Interest income financial investments, including 38 108 125 Interest income non-current financial receivables 26 34 21 Interest income other current financial assets and other 48 113 281 Interest income and other financial items 151 298 502 Gains/(losses) financial investments (348) 456 243 Gains/(losses) other derivative financial instruments (708) 448 473 Interest expense bonds and bank loans and net (896) (951) (987) Interest expense lease liabilities (93) (104) (126) Capitalised borrowing costs 334 308 480 Accretion expense asset retirement obligations (453) (412) (456) Interest expense current financial liabilities and (114) (232) (360) Interest and other finance expenses (1,223) (1,392) (1,450) Net financial items (2,080) (836) (7)

Income taxes (Tables)

Income taxes (Tables)	12 Months Ended
	Dec. 31, 2021
Income tax [abstract]
Significant components of income tax expense [Table Text Block]	Significant components of income tax expense Full year (in USD million) 2021 2020 2019 Current income tax expense in respect of (21,271) (1,115) (7,892) Prior period adjustments (28) 313 69 Current income tax expense (21,299) (802) (7,822) Origination and reversal of temporary differences (1,778) (648) 410 Recognition of previously unrecognised deferred 126 130 0 Change in tax regulations 4 (12) (6) Prior period adjustments (60) 94 (23) Deferred tax income/(expense) (1,708) (435) 381 Income tax (23,007) (1,237) (7,441)
Reconciliation of statutory tax rate to effective tax rate [Table Text Block]	Reconciliation of statutory tax rate to effective Full year (in USD million) 2021 2020 2019 Income/(loss) before tax 31,583 (4,259) 9,292 Calculated income tax at statutory rate 1) (7,053) 1,445 (2,284) Calculated Norwegian Petroleum tax 2) (17,619) (2,126) (5,499) Tax effect uplift 3) 914 1,006 632 Tax effect of permanent differences regarding divestments 90 (9) 380 Tax effect of permanent differences caused by functional currency different from tax currency 150 (198) 8 Tax effect of other permanent differences 228 450 395 Recognition of previously unrecognised deferred tax 126 130 0 Change in unrecognised deferred tax assets 619 (1,685) (974) Change in tax regulations 4 (12) (6) Prior period adjustments (88) 408 47 Other items including foreign currency effects (378) (647) (139) Income tax (23,007) (1,237) (7,441) Effective tax rate 72.8% -29.0% 80.1% The weighted average of statutory tax rates was 22.3 % in 2021, 33.9 % in 2020 and 24.6 % in 2019. The rates are influenced by earnings composition between tax regimes with lower statutory tax rates and tax regimes with 2) 56 %. 3) 56 % on income from the Norwegian continental shelf, an additional tax-free allowance, uplift, is granted on the basis of the original capitalised cost of offshore production installations. Normally, a 5.2 % uplift may be deducted from taxable income for a period of four years starting in the year in which the and 2021 temporary rules allow direct deduction of the whole uplift at a rate of 24 % in the year the capital expenditure is incurred. For investments made in 2019 the uplift is calculated at a rate of 5.2 % per year, while the rate is 5.3 % per year for investments made in 2018 and 7.5 % per year for investments under the transitional rules from 2013. Unused uplift may indefinitely. At year-end 2021 and 2020, unrecognised uplift credits amounted to USD 272 836 respectively.
Deferred tax assets and liabilities [text block]	Deferred tax assets and liabilities comprise (in USD million) Tax losses carried forward Property, plant and equipment and intangible assets 1) Asset retirement obligations 1) Lease liabilities Pensions Derivatives Other Total Deferred tax at 31 December 2021 Deferred tax assets 5,162 719 11,256 1,506 804 21 2,015 21,484 Deferred tax liabilities 0 (27,136) 0 0 (21) (1,453) (530) (29,140) Net asset/(liability) at 31 December 2021 5,162 (26,417) 11,256 1,506 783 (1,432) 1,485 (7,655) Deferred tax at 31 December 2020 Deferred tax assets 4,676 826 12,967 1,869 787 30 1,811 22,966 Deferred tax liabilities 0 (28,290) 0 (4) (11) (236) (676) (29,217) Net asset/(liability) at 31 December 2020 4,676 (27,464) 12,967 1,865 777 (206) 1,135 (6,250) Restated 2020 figures due to a policy change affecting ARO calculation, see note 2 Significant accounting policies. The deferred tax liability in Property, plant and equipment and intangible assets has increased by USD 1.762 deferred tax asset in Asset retirement obligations has increased by USD 1.762
Changes in net deferred tax liability during the year [Table Text Block]	Changes in net deferred tax liability during (in USD million) 2021 2020 2019 Net deferred tax liability at 1 January 6,250 5,530 5,367 Charged/(credited) to the Consolidated statement of 1,708 435 (381) Charged/(credited) to Other comprehensive income 35 (19) 98 Foreign currency translation effects and other effects (337) 304 446 Net deferred tax liability at 31 December 7,655 6,250 5,530
Disclosure of Net deferred tax assets and liabilities [Table Text Block]	At 31 December (in USD million) 2021 2020 Deferred tax assets 6,259 4,974 Deferred tax liabilities 14,037 11,224 Deferred tax assets reported in Assets classified as 122 0
Disclosure of unrecognised deferred tax assets [Table Text Block]	Unrecognised deferred tax assets At 31 December 2021 2020 (in USD million) Basis Tax Basis Tax Deductible temporary differences 2,900 1,203 2,866 1,204 Unused tax credits 0 264 0 212 Tax losses carried forward 20,552 5,047 23,434 5,677 Total unrecognised deferred tax assets 23,452 6,514 26,300 7,093

Property, plant and equipment (

Property, plant and equipment (Tables)	12 Months Ended
	Dec. 31, 2021
Property, plant and equipment [abstract]
Property, plant and equipment [text block]	(in USD million) Machinery, equipment and transportation equipment Production plants and oil and gas assets Refining and manufacturing plants Buildings and land Assets under development Right of use assets 4) Total Cost at 31 December 2020 as reported 2,806 180,355 9,238 929 13,053 6,370 212,751 Impact of policy change 5) - 2,726 - - 110 - 2,836 Cost at 31 December 2020 as restated 2,806 183,082 9,238 929 13,163 6,370 215,587 Additions through business combinations 0 2 0 0 1 0 4 Additions and transfers 39 7,311 95 27 (396) 148 7,225 Disposals at cost (1,496) (1,975) (70) (353) (25) (501) (4,420) Assets reclassified to held for sale 0 (1,010) (563) 0 0 (91) (1,664) Foreign currency translation effects (13) (4,052) (220) (6) (130) (77) (4,497) Cost at 31 December 2021 1,335 183,358 8,481 596 12,614 5,850 212,234 Accumulated depreciation and impairment losses at 31 December 2020 (2,596) (132,427) (8,005) (524) (1,275) (2,251) (147,079) Depreciation (68) (9,136) (232) (42) 0 (930) (10,408) Impairment losses (42) (2,092) (401) (21) (390) (17) (2,962) Reversal of impairment losses 0 1,675 0 0 0 2 1,677 Transfers 61 (1,319) 0 (61) 1,319 (11) (11) Accumulated depreciation and impairment on disposed assets 1,448 1,785 59 326 21 480 4,118 Accumulated depreciation and impairment assets classified as held for sale 0 825 461 0 0 82 1,367 Foreign currency translation effects 9 2,926 192 2 (18) 27 3,138 Accumulated depreciation and impairment losses at 31 December 2021 (1,188) (137,763) (7,926) (320) (344) (2,619) (150,159) Carrying amount at 31 December 2021 147 45,595 555 276 12,270 3,231 62,075 Estimated useful lives (years) UoP 1) 2) 3) (in USD million) Machinery, equipment and transportation equipment Production plants and oil and gas assets Refining and manufacturing plants Buildings and land Assets under development Right of use assets 4) Total Cost at 31 December 2019 as reported 2,818 179,063 8,920 909 10,371 5,339 207,422 Impact of policy change 5) - 1,762 - - 37 - 1,799 Cost at 31 December 2019 as restated 2,818 180,825 8,920 909 10,408 5,339 209,221 Additions and transfers 68 7,782 110 27 2,478 968 11,433 Disposals at cost (28) (243) (7) 0 (5) (13) (295) Assets reclassified to held for sale (66) (9,095) 0 (15) (159) 0 (9,335) Foreign currency translation effects 13 3,812 214 7 441 75 4,563 Cost at 31 December 2020 2,806 183,082 9,238 929 13,163 6,370 215,587 Accumulated depreciation and impairment losses at 31 December 2019 (2,395) (125,327) (7,051) (475) (892) (1,329) (137,469) Depreciation (102) (8,240) (248) (23) 0 (874) (9,488) Impairment losses (201) (4,667) (516) (36) (445) (25) (5,889) Reversal of impairment losses 0 218 0 0 0 0 218 Transfers 18 (68) (1) 0 41 0 (10) Accumulated depreciation and impairment on disposed assets 27 231 7 0 1 11 278 Accumulated depreciation and impairment assets classified as held for sale 65 8,373 0 12 75 0 8,525 Foreign currency translation effects (9) (2,947) (196) (3) (56) (35) (3,244) Accumulated depreciation and impairment losses at 31 December 2020 (2,596) (132,427) (8,005) (524) (1,275) (2,251) (147,079) Carrying amount at 31 December 2020 209 50,654 1,232 405 11,888 4,119 68,508 Estimated useful lives (years) UoP 1) 2) 3) Depreciation according to unit of production method (UoP), see note 2 Significant accounting policies . 2) . Buildings include leasehold improvements. 3) 4) 5) lines are also impacted by the policy change.
Impairments [text block]	Full year Property, plant and equipment 3) (in USD million) 2021 2020 2019 2021 2020 2019 2021 2020 2019 Producing and development assets 1) 1,285 5,671 3,230 (2) 680 608 1,283 6,351 3,838 Goodwill 1) 1 42 164 1 42 164 Other intangible assets 1) 0 8 41 0 8 41 Acquisition costs related to oil and gas prospects 2) 154 657 49 154 657 49 Total net impairment loss/(reversal) recognised 1,285 5,671 3,230 154 1,386 863 1,439 7,057 4,093 Producing and development assets, refining and manufacturing plants, goodwill and other intangible assets are impairment assessment under IAS 36. The total net impairment losses recognised under IAS 36 in 2021 1.285 billion, compared to 2020 when the net impairment amounted to USD 6.401 and gas prospects (intangible assets). 2) 6). 3) .
Impairment of the carrying amount of impaired asset [text block]	At 31 December 2021 At 31 December 2020 (in USD million) Valuation method Carrying amount after impairment Net impairment loss/ (reversal) Carrying amount after impairment Net impairment loss/ (reversal) Exploration & Production Norway VIU 5,379 (1,102) 7,042 1,219 Exploration & Production USA - onshore VIU 1,979 8 4,676 (19) FVLCOD 0 40 1,122 2,331 Exploration & Production USA - offshore Gulf of Mexico VIU 798 18 2,808 305 North America - offshore other areas VIU 0 0 53 146 FVLCOD 0 (22) 0 0 Europe and Asia VIU 1,566 1,609 3,687 1,280 Marketing, Midstream & Processing VIU 632 486 1,297 824 FVLCOD 236 230 668 228 Right of use assets/Other VIU 16 (2) 265 36 FVLCOD 4 17 0 0 Total 10,610 1,282 21,619 6,351

Intangible assets (Tables)

Intangible assets (Tables)	12 Months Ended
	Dec. 31, 2021
Disclosure of intangible assets [abstract]
Continuity schedule of intangible assets [text block]	(in USD million) Exploration expenses Acquisition costs - oil and gas prospects Goodwill Other Total Cost at 31 December 2020 2,261 3,932 1,481 831 8,505 Additions through business combinations 0 0 61 55 116 Additions 191 36 0 35 262 Disposals at cost (22) 1 (3) (29) (53) Transfers (432) (1,137) 0 (161) (1,730) Expensed exploration expenditures previously capitalised (19) (152) 0 0 (171) Impairment of goodwill 0 0 (1) 0 (1) Foreign currency translation effects (21) (10) (70) (10) (111) Cost at 31 December 2021 1,958 2,670 1,467 722 6,816 Accumulated depreciation and impairment losses (356) (356) Amortisation and impairments for the year (24) (24) Amortisation and impairment losses disposed intangible 13 13 Foreign currency translation effects 3 3 Accumulated depreciation and impairment losses (364) (364) Carrying amount at 31 December 2021 1,958 2,670 1,467 358 6,452 (in USD million) Exploration expenses Acquisition costs - oil and gas prospects Goodwill Other Total Cost at 31 December 2019 3,014 5,599 1,458 962 11,033 Additions 401 67 0 24 492 Disposals at cost (7) 0 0 0 (8) Transfers (16) (73) 0 0 (89) Assets reclassified to held for sale 0 (339) 0 (160) (499) Expensed exploration expenditures previously capitalised (1,169) (1,337) 0 0 (2,506) Impairment of goodwill 0 0 (42) 0 (42) Foreign currency translation effects 38 16 64 6 123 Cost at 31 December 2020 2,261 3,932 1,481 831 8,505 Accumulated depreciation and impairment losses (295) (295) Amortisation and impairments for the year (35) (35) Accumulated depreciation and impairment assets sale (17) (17) Amortisation and impairment losses disposed intangible (6) (6) Foreign currency translation effects (3) (3) Accumulated depreciation and impairment losses (356) (356) Carrying amount at 31 December 2020 2,261 3,932 1,481 475 8,149
Aging of capitalised exploration expenditures [text block]	The table below shows the aging of capitalised exploration expenditures. (in USD million) 2021 2020 Less than one year 234 604 Between one and five years 692 623 More than five years 1,033 1,033 Total capitalised exploration expenditures 1,958 2,261
Components of the exploration expenses [text block]	The table below shows the components of the exploration Full year (in USD million) 2021 2020 2019 Exploration expenditures 1,027 1,371 1,584 Expensed exploration expenditures previously capitalised 171 2,506 777 Capitalised exploration (194) (394) (507) Exploration expenses 1,004 3,483 1,854

Equity accounted investments (T

Equity accounted investments (Tables)	12 Months Ended
	Dec. 31, 2021
Equity accounted investments [Abstract]
Equity accounted investments [text block]	(in USD million) 2021 2020 Net investments at 1 January 2,270 1,487 Net income/(loss) from equity accounted investments 259 53 Acquisitions and increase in capital 475 995 Dividend and other distributions (230) (141) Other comprehensive income/(loss) (58) 21 Divestments, derecognition and decrease in paid in (31) (147) Net investments at 31 December 2,686 2,270 Included in equity accounted investments 2,686 2,262 Other long-term receivable in equity accounted investments 0 8

Financial investments and fin_2

Financial investments and financial receivables (Tables)	12 Months Ended
	Dec. 31, 2021
Financial investments and financial receivables [abstract]
Disclosure Of Noncurrent Financial Assets Explanatory [Table Text Block]	Non-current financial investments At 31 December (in USD million) 2021 2020 Bonds 1,822 1,866 Listed equity securities 778 1,648 Non-listed equity securities 746 569 Financial investments 3,346 4,083
Disclsoure Of Prepayments And Financial Receivables Explanatory [Table Text Block]	Non-current prepayments and financial receivables At 31 December (in USD million) 2021 2020 Interest bearing financial receivables 707 465 Other interest bearing receivables 276 246 Prepayments and other non-interest bearing receivables 104 150 Prepayments and financial receivables 1,087 861
Disclosure of other current assets [text block]	Current financial investments At 31 December (in USD million) 2021 2020 Time deposits 7,060 4,841 Interest bearing securities 14,186 7,010 Listed equity securities 0 13 Financial investments 21,246 11,865

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2021
Inventories [abstract]
Disclosure Of Detailed Information About Inventories Explanatory [Table Text Block]	At 31 December (in USD million) 2021 2020 Crude oil 2,014 2,022 Petroleum products 315 443 Natural gas 642 229 Other 424 390 Inventories 3,395 3,084

Trade and other receivables (Ta

Trade and other receivables (Tables)	12 Months Ended
	Dec. 31, 2021
Trade and other receivables [abstract]
Trade and other receivables [text block]	At 31 December (in USD million) 2021 2020 Trade receivables from contracts with customers 13,266 5,729 Other current receivables 3,011 1,275 Joint venture receivables 491 340 Receivables from equity accounted associated companies 423 74 Total financial trade and other receivables 17,191 7,418 Non-financial trade and other receivables 736 814 Trade and other receivables 17,927 8,232

Cash and cash equivalents (Tabl

Cash and cash equivalents (Tables)	12 Months Ended
	Dec. 31, 2021
Cash and cash equivalents [abstract]
Cash and cash equivalents [text block]	At 31 December (in USD million) 2021 2020 Cash at bank available 2,673 1,648 Time deposits 1,906 1,132 Money market funds 2,714 492 Interest bearing securities 4,740 2,485 Restricted cash, including margin deposits 2,093 999 Cash and cash equivalents 14,126 6,757

Shareholders' equity and divi_2

Shareholders' equity and dividends (Tables)	12 Months Ended
	Dec. 31, 2021
Shareholders equity and dividends [Abstract]
Dividends	At 31 December (in USD million) 2021 2020 Dividends declared 2,041 1,833 USD per share or ADS 0.6300 0.5600 Dividends paid 1,797 2,330 USD per share or ADS 0.5600 0.7100 NOK per share 4.8078 6.7583
Share buy-back programme	Number of shares 2021 2020 Share buy-back programme at 1 January 0 23,578,410 Purchase 13,460,292 3,142,849 Cancellation 0 (26,721,259) Share buy-back programme at 31 December 13,460,292 0
Treasury shares	Employees share saving plan Number of shares 2021 2020 Share saving plan at 1 January 11,442,491 10,074,712 Purchase 3,412,994 4,604,106 Allocated to employees (2,744,381) (3,236,327) Share saving plan at 31 December 12,111,104 11,442,491

Finance debt (Tables)

Finance debt (Tables)	12 Months Ended
	Dec. 31, 2021
Finance debt [abstract]
Disclosure of detailed information about borrowings [table text block]	Non-current finance debt Finance debt measured at amortised cost Weighted average interest rates in % 1) Carrying amount in USD millions at 31 December Fair value in USD millions at 31 December 2) 2021 2020 2021 2020 2021 2020 Unsecured bonds United States Dollar (USD) 3.88 3.82 17,451 18,710 19,655 21,883 Euro (EUR) 1.42 2.03 7,925 10,057 8,529 11,115 Great Britain Pound (GBP) 6.08 6.08 1,852 1,877 2,674 2,949 Norwegian Kroner (NOK) 4.18 4.18 340 352 380 412 Total unsecured bonds 27,568 30,994 31,237 36,359 Unsecured loans Japanese Yen (JPY) 4.30 4.30 87 97 106 119 Total unsecured loans 87 97 106 119 Total 27,655 31,091 31,343 36,479 Non-current finance debt due within one year 250 1,974 268 2,062 Non-current finance debt 27,404 29,118 31,075 34,417 Weighted average interest rates are calculated based on the contractual rates on the loans per currency at 31 December not include the effect of swap agreements. 2) level 2 in the fair value hierarchy. For more information regarding fair value hierarchy, see note 26 Financial Instruments: fair value measurement and sensitivity of market risk.
Disclosure Of Bonds Issued [text block]	In 2020 and 2021 Equinor issued the following Issuance date Currency Amount in million Interest rate in % Maturity date 18 May 2020 USD 750 1.750 January 2026 18 May 2020 EUR 750 0.750 May 2026 18 May 2020 USD 750 2.375 May 2030 18 May 2020 EUR 1,000 1.375 May 2032 1 April 2020 USD 1,250 2.875 April 2025 1 April 2020 USD 500 3.000 April 2027 1 April 2020 USD 1,500 3.125 April 2030 1 April 2020 USD 500 3.625 April 2040 1 April 2020 USD 1,250 3.700 April 2050
Disclosure of Non-current finance debt maturity profile [text block]	Non-current finance debt maturity profile At 31 December (in USD million) 2021 2020 Year 2 and 3 5,015 3,705 Year 4 and 5 4,731 4,927 After 5 years 17,659 20,485 Total repayment of non-current finance debt 27,404 29,118 Weighted average maturity (years - including current portion) 10 10 Weighted average annual interest rate (% - including current portion) 3.33 3.38
Disclosure of Current finance debt [text block]	Current finance debt At 31 December (in USD million) 2021 2020 Collateral liabilities 2,271 1,704 Non-current finance debt due within one year 250 1,974 Other including US Commercial paper program 2,752 913 Total current finance debt 5,273 4,591 Weighted average interest rate (%) 0.51 2.40
Reconciliation of liabilities arising from financing activities [text block]	Reconciliation of cash flows from financing activities (in USD million) Non-current finance debt Current finance debt Financial receivable Collaterals 1) Additional paid in capital /Treasury shares Non- controlling interest Dividend payable Lease liabilities 2) Total At 1 January 2021 29,118 4,591 (967) (1,588) 19 357 4,406 New finance debt Repayment of finance debt (2,675) (2,675) Repayment of lease liabilities (1,238) (1,238) Dividend paid (1,797) (1,797) Share buy-back (321) (321) Net current finance debt and other finance activities (335) 2,273 (651) (75) (18) 1,195 Net cash flow from financing activities (3,010) 2,273 (651) (396) (18) (1,797) (1,238) (4,836) Transfer to current portion 1,724 (1,724) Effect of exchange rate changes (422) (8) 41 (1) (61) Dividend declared 2,041 New leases 476 Other changes (6) 141 (43) 14 (19) (21) Net other changes 1,296 (1,591) 41 (43) 13 2,022 394 At 31 December 2021 27,404 5,273 (1,577) (2,027) 14 582 3,562 (in USD million) Non-current finance debt Current finance debt Financial receivable Collaterals 1) Additional paid in capital /Treasury shares Non- controlling interest Dividend payable Lease liabilities 2) Total At 1 January 2020 21,754 2,939 (634) (708) 20 859 4,339 New finance debt 8,347 8,347 Repayment of finance debt (2,055) (2,055) Repayment of lease liabilities (1,277) (1,277) Dividend paid (2,330) (2,330) Share buy-back (1,059) (1,059) Net current finance debt and other finance activities 72 1,706 (329) (69) (16) 1,365 Net cash flow from financing activities 6,364 1,706 (329) (1,128) (16) (2,330) (1,277) 2,991 Transfer to current portion 30 (30) Effect of exchange rate changes 977 (27) 15 Dividend declared 1,833 New leases 1,349 Other changes (8) 3 (4) 248 15 (20) (5) Net other changes 999 (54) (4) 248 15 1,828 1,344 At 31 December 2020 29,118 4,591 (967) (1,588) 19 357 4,406 1) Financial receivable collaterals are included in other receivables for more information. 2) See note 23 Leases for more information.

Pensions (Tables)

Pensions (Tables)	12 Months Ended
	Dec. 31, 2021
Disclosure of defined benefit plans [abstract]
Net pension cost [table text block]	Net pension cost (in USD million) 2021 2020 2019 Current service cost 209 184 206 Past service cost 3 - - Losses/(gains) from curtailment, settlement or plan - - 3 Notional contribution plans 60 55 56 Defined benefit plans 272 238 265 Defined contribution plans 213 192 182 Total net pension cost 488 432 446
Disclosure of defined benefit plans [table text block]	Changes in defined benefit obligations (DBO) and (in USD million) 2021 2020 DBO at 1 January 9,216 8,363 Current service cost 208 184 Interest cost 238 203 Actuarial (gains)/losses - Financial assumptions 294 443 Actuarial (gains)/losses - Experience (66) (61) Past service cost 3 - Benefits paid (295) (250) Paid-up policies - (7) Foreign currency translation effects (300) 286 Changes in notional contribution liability 60 55 DBO at 31 December 9,358 9,216 Fair value of plan assets at 1 January 6,234 5,589 Interest income 106 117 Return on plan assets (excluding interest income) 291 385 Company contributions 114 96 Benefits paid (137) (113) Paid-up policies and personal insurance - (7) Foreign currency translation effects (204) 167 Fair value of plan assets at 31 December 6,404 6,234 Net pension liability at 31 December (2,954) (2,981) Represented by: Asset recognised as non-current pension assets 1,449 1,310 Liability recognised as non-current pension liabilities (4,403) (4,292) DBO specified by funded and unfunded pension plans 9,359 9,216 Funded 4,959 4,927 Unfunded 4,400 4,288 Actual return on assets 397 501
Actuarial losses and gains recognised directly in Other comprehensive income [text block]	Actuarial losses and gains recognised directly (in USD million) 2021 2020 2019 Net actuarial (losses)/gains recognised in OCI 63 3 401 Foreign currency translation effects 84 (109) 27 Tax effects of actuarial (losses)/gains recognised in OCI (35) 19 (98) Recognised directly in OCI during the year, net of tax 112 (87) 330 Cumulative actuarial (losses)/gains recognised directly (787) (899) (812)
Actuarial assumptions [text block]	Actuarial assumptions Assumptions used to determine benefit costs in % Assumptions used to determine benefit obligations in % Rounded to the nearest quartile 2021 2020 2021 2020 Discount rate 1.75 2.25 2.00 1.75 Rate of compensation increase 2.00 2.25 2.50 2.00 Expected rate of pension increase 1.25 1.50 1.75 1.25 Expected increase of social security base amount (G-amount) 2.00 2.25 2.25 2.00 Weighted-average duration of the defined benefit obligation 15.2 15.6
Disclosure of sensitivity analysis for actuarial assumptions [table text block]	Discount rate Expected rate of compensation increase Expected rate of pension increase Mortality assumption (in USD million) 0.50% -0.50% 0.50% -0.50% 0.50% -0.50% + 1 year - 1 year Effect on: Defined benefit obligation at 31 December 2021 (645) 731 157 (150) 601 (545) 367 (330) Service cost 2022 (20) 24 10 (9) 16 (14) 8 (7)
Portfolio weighting as approved by the board of Statoil Pension [text block]	Pension assets on investments classes Target portfolio weight (in %) 2021 2020 Equity securities 34.1 34.1 29-38 Bonds 50.2 50.2 46-59 Money market instruments 9.1 9.4 0-14 Real estate 6.6 6.4 5-10 Other assets, including derivatives 0.0 (0.1) Total 100.0 100.0

Provisions and other liabilit_2

Provisions and other liabilities (Tables)	12 Months Ended
	Dec. 31, 2021
Provisions and other liabilities [abstract]
Disclosure of other provisions [table text block]	(in USD million) Asset retirement obligations Claims and litigations Other provisions and liabilities Total Non-current portion at 31 December 2020 before 17,200 96 2,436 19,731 Impact of ARO policy change 2,837 - - 2,837 Non-current portion at 31 December 2020 after restatement 20,037 96 2,436 22,568 Current portion at 31 December 2020 reported provisions 92 958 1,600 2,649 Provisions and other liabilities at 31 December 2020 20,128 1,053 4,035 25,216 New or increased provisions and other liabilities 602 30 352 984 Change in estimates (1,097) (58) (141) (1,296) Amounts charged against provisions and other liabilities (125) (870) (524) (1,519) Effects of change in the discount rate (1,610) - (13) (1,623) Reduction due to divestments (359) - - (359) Accretion expenses 423 - 29 452 Reclassification and transfer (74) - 298 224 Foreign currency translation effects (471) - (5) (476) Provisions and other liabilities at 31 December 2021 17,417 155 4,031 21,603 Non-current portion at 31 December 2021 17,279 81 2,539 19,899 Current portion at 31 December 2021 reported provisions 138 73 1,493 1,704
Other provisions maturity [table text block]	Expected timing of cash outflows (in USD million) Asset retirement obligations Other provisions and liabilities, including claims and litigations Total 2022 - 2026 1,180 3,014 4,194 2027 - 2031 1,597 299 1,896 2032 - 2036 4,315 248 4,563 2037 - 2041 6,152 55 6,207 Thereafter 4,173 569 4,742 At 31 December 2021 17,417 4,186 21,603
Restatement of ARO due to change in the discount rate [table text block]	Line items impacted in the consolidated balance sheet (in USD million) 01.01.2020 before restatement Impact of ARO policy change 01.01.2020 after restatement 31.12.2020 before restatement Impact of ARO policy change 31.12.2020 after restatement PPE 69,953 1,798 71,751 65,672 2,836 68,508 Total non-current assets 93,285 1,798 95,083 89,786 2,836 92,623 Total assets 118,063 1,798 119,861 121,972 2,836 124,809 Provisions and other liabilities 17,951 1,798 19,749 19,731 2,837 22,568 Total non-current liabilities 57,346 1,798 59,144 68,260 2,837 71,097 Total liabilities 76,904 1,798 78,702 88,081 2,837 90,917

Trade, other payables and pro_2

Trade, other payables and provisions (Tables)	12 Months Ended
	Dec. 31, 2021
Trade, other payables and provisions [abstract]
Disclosure Of Detailed Information Of Trade And Other Payables [table text block]	At 31 December (in USD million) 2021 2020 Trade payables 6,249 2,748 Non-trade payables and accrued expenses 2,181 2,352 Joint venture payables 1,876 2,090 Payables to equity accounted associated companies 2,045 546 Total financial trade and other payables 12,351 7,736 Current portion of provisions and other non-financial 1,960 2,774 Trade, other payables and provisions 14,310 10,510

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2021
Disclosure of reconciliation of liabilities arising from financing activities [line items]
Lease payments not included in lease liability	Information related to lease payments and lease (in USD million) 2021 2020 Lease liabilities at 1 January 4,406 4,339 New leases, including remeasurements and cancellations 476 1,349 Gross lease payments (1,350) (1,415) Lease interest 91 102 Lease repayments (1,259) (1,259) (1,313) (1,313) Foreign currency translation effects (61) 31 Lease liabilities at 31 December 3,562 4,406 Current lease liabilities 1,113 1,186 Non-current lease liabilities 2,449 3,220 Lease expenses not included in lease liabilities (in USD million) 2021 2020 Short-term lease expenses 160 342
Non-current lease liabilities maturity profile	Non-current lease liabilities maturity profile At 31 December (in USD million) 2021 2020 Year 2 and 3 1,164 1,513 Year 4 and 5 586 748 After 5 years 699 959 Total repayment of non-current lease liabilities 2,449 3,220
Information related to Right of use assets	Information related to Right of use assets (in USD million) Drilling rigs Vessels Land and buildings Storage facilities Other Total Right of use assets at 1 January 2021 1,004 1,606 1,215 133 161 4,119 Additions, divestments 14 300 28 8 78 427 Depreciation and impairment 1) (316) (617) (176) (72) (82) (1,265) Foreign currency translation effects (26) (8) (12) 0 (5) (50) Right of use assets at 31 December 2021 675 1,280 1,055 68 152 3,231 (in USD million) Drilling rigs Vessels Land and buildings Storage facilities Other Total Right of use assets at 1 January 2020 951 1,320 1,365 156 219 4,011 Additions, divestments 380 853 18 45 30 1,326 Depreciation and impairment 1) (349) (571) (179) (68) (90) (1,257) Foreign currency translation effects 23 4 11 0 2 40 Right of use assets at 31 December 2020 1,004 1,606 1,215 133 161 4,119 1) USD 320 million in 2021 and USD 359 11 Property,
Lease liabilities [member]
Disclosure of reconciliation of liabilities arising from financing activities [line items]
Information related to lease payments and lease liabilities	Information related to lease payments and lease (in USD million) 2021 2020 Lease liabilities at 1 January 4,406 4,339 New leases, including remeasurements and cancellations 476 1,349 Gross lease payments (1,350) (1,415) Lease interest 91 102 Lease repayments (1,259) (1,259) (1,313) (1,313) Foreign currency translation effects (61) 31 Lease liabilities at 31 December 3,562 4,406 Current lease liabilities 1,113 1,186 Non-current lease liabilities 2,449 3,220 Lease expenses not included in lease liabilities (in USD million) 2021 2020 Short-term lease expenses 160 342

Other commitments, contingent_2

Other commitments, contingent liabilities and contingent assets (Tables)	12 Months Ended
	Dec. 31, 2021
Disclosure of other commitments, contingent liabilities and contingent assets [abstract]
Disclosure of commitments [text block]	(in USD million) 2022 2,663 2023 2,077 2024 1,520 2025 1,307 2026 1,026 Thereafter 4,547 Total other long-term commitments 13,140

Financial instruments_ fair v_2

Financial instruments: fair value measurement and sensitivity analysis of market risk (Tables)	12 Months Ended
	Dec. 31, 2021
Disclosure of Financial instruments: fair value measurement and sensitivity analysis of market risk [abstract]
Disclosure of financial assets [text block]	At 31 December 2021 Fair value through profit or loss Non-financial assets Total carrying amount (in USD million) Note Amortised cost Assets Non-current derivative financial instruments 1,265 1,265 Non-current financial investments 14 253 3,093 3,346 Prepayments and financial receivables 14 707 380 1,087 Trade and other receivables 16 17,192 736 17,927 Current derivative financial instruments 5,131 5,131 Current financial investments 14 20,946 300 21,246 Cash and cash equivalents 17 11,412 2,714 14,126 Total financial assets 50,510 12,503 1,116 64,128 At 31 December 2020 Fair value through profit or loss Non-financial assets Total carrying amount (in USD million) Note Amortised cost Assets Non-current derivative financial instruments 2,476 2,476 Non-current financial investments 14 261 3,822 4,083 Prepayments and financial receivables 1) 14 465 396 861 Trade and other receivables 16 7,418 814 8,232 Current derivative financial instruments 886 886 Current financial investments 14 11,649 216 11,865 Cash and cash equivalents 17 6,264 492 6,757 Total financial assets 26,057 7,892 1,210 35,159 1) The categories Amortised cost and Non-financial assets incorrect classification of USD 32 million in 2020.
Disclosure of financial liabilities [text block]	At 31 December 2021 Amortised cost Fair value through profit or loss Non-financial liabilities Total carrying amount (in USD million) Note Liabilities Non-current finance debt 19 27,404 27,404 Non-current derivative financial instruments 767 767 Trade, other payables and provisions 22 12,350 1,960 14,310 Current finance debt 19 5,273 5,273 Dividend payable 582 582 Current derivative financial instruments 4,609 4,609 Total financial liabilities 45,609 5,376 1,960 52,945 At 31 December 2020 Amortised cost Fair value through profit or loss Non-financial liabilities Total carrying amount (in USD million) Note Liabilities Non-current finance debt 19 29,118 29,118 Non-current derivative financial instruments 676 676 Trade, other payables and provisions 22 7,736 2,774 10,510 Current finance debt 19 4,591 4,591 Dividend payable 357 357 Current derivative financial instruments 1,710 1,710 Total financial liabilities 41,802 2,386 2,774 46,961
Disclosure of fair value measurement [text block]	(in USD million) Non-current financial investments Non-current derivative financial instruments - assets Current financial investments Current derivative financial instruments - assets Cash equivalents Non-current derivative financial instruments - liabilities Current derivative financial instruments - liabilities Net fair value At 31 December 2021 Level 1 860 0 - 949 0 (69) 1,740 Level 2 1,840 884 300 4,108 2,714 (762) (4,539) 4,545 Level 3 393 380 74 (4) 843 Total fair value 3,093 1,265 300 5,131 2,714 (767) (4,609) 7,127 At 31 December 2020 Level 1 1,379 - 66 419 - (432) 1,432 Level 2 2,135 2,146 150 443 492 (671) (1,277) 3,418 Level 3 308 330 24 (5) 657 Total fair value 3,822 2,476 216 886 492 (676) (1,710) 5,505
Reconciliation of fair value changes in financial instruments [Table text block]	(in USD million) Non-current financial investments Non-current derivative financial instruments - assets Current derivative financial instruments - assets Non-current derivative financial instruments - liabilities Total amount Opening at 1 January 2021 308 330 24 (5) 657 Total gains and losses recognised in statement of income (23) 58 72 1 108 Purchases 119 119 Settlement (7) (20) (27) Transfer out of level 3 - - Foreign currency translation effects (3) (8) (2) (13) Closing at 31 December 2021 394 380 74 (4) 844 Opening at 1 January 2020 277 219 33 (19) 510 Total gains and losses recognised in statement of income (29) 106 19 14 109 Purchases 64 64 Settlement (8) (28) (36) Transfer to level 1 1 1 Foreign currency translation effects 4 5 - 9 Closing at 31 December 2020 308 330 24 (5) 657
Commodity price sensitivity [member]
Disclosure of risk management strategy related to hedge accounting [line items]
Sensitivity analysis for types of market risk [text block]	Commodity price sensitivity At 31 December 2021 2020 (in USD million) - 30% + 30% - 30% + 30% Crude oil and refined products net gains/(losses) 735 (735) 1,025 (1,025) Natural gas, electricity and CO2 net gains/(losses) 227 (141) 184 (94)
Currency risk sensitivity [member]
Disclosure of risk management strategy related to hedge accounting [line items]
Sensitivity analysis for types of market risk [text block]	Currency risk sensitivity At 31 December 2021 2020 (in USD million) - 10 % + 10% - 8 % + 8% USD net gains/(losses) (1,789) 1,789 (319) 319 NOK net gains/(losses) 2,144 (2,144) 322 (322)
Interest rate sensitivity [member]
Disclosure of risk management strategy related to hedge accounting [line items]
Sensitivity analysis for types of market risk [text block]	Interest risk sensitivity At 31 December 2021 2020 (in USD million) points + 0.8 percentage points points + 0.6 percentage points Positive/(negative) impact on net financial items 448 (448) 516 (516)
Equity price risk [member]
Disclosure of risk management strategy related to hedge accounting [line items]
Sensitivity analysis for types of market risk [text block]	Equity price sensitivity At 31 December 2021 2020 (in USD million) - 35% + 35% - 35% + 35% Net gains/(losses) (534) 534 (684) 684

Organisation (Details)

Organisation (Details)	12 Months Ended
	Dec. 31, 2021
Organisation [Abstract]
Name of reporting entity or other means of identification	Equinor ASA
Domicile of entity	Norway
Country of incorporation	Norway
Address of entity's registered office	Forusbeen 50, N-4035 Stavanger, Norway
Description of nature of entity's operations and principal activities	The Equinor group's business consists principally of the exploration, production, transportation, refining and marketing of petroleum and petroleum-derived products and other forms of energy.

Significant accounting polici_2

Significant accounting policies (Details)	12 Months Ended
	Dec. 31, 2021$ / t
Significant accounting policies [Abstract]
Internal carbon price	58

Consequences of initiatives t_2

Consequences of initiatives to limit climate changes (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)$ / tkr / t€ / t	Dec. 31, 2020USD ($)€ / t
Climate changes [line items]
Impairment exposure due to net zero emission	$ 9,000
Internal carbon price | $ / t	58
External carbon price | € / t		56
Expense related to carbon emissions and purchase	$ 428	$ 268
Next two years [member]
Climate changes [line items]
External carbon price | € / t		80
2030 and thereafter [member]
Climate changes [line items]
Internal carbon price | $ / t	100
External carbon price | € / t	65	27.5
Expected tax increase on carbon emissions maximum | kr / t	2,000
2050 [member]
Climate changes [line items]
Impairment exposure due to net zero emission	$ 7,000
External carbon price | € / t	100	41
Oil and Gas prospects, signature bonuses and the capitalised exploration costs [Member]
Climate changes [line items]
Total carrying value of intangible assets	$ 4,600
Asset retirement obligations [Member]
Climate changes [line items]
Increase in liability	$ 200

Segments - Segment Data (Detail

Segments - Segment Data (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of operating segments [line items]
Revenues third party, other revenues and other income	$ 90,665	$ 45,765	$ 64,194
Revenues inter-segment	0	0	0
Net income/(loss) from equity accounted investments	259	53	164
Total revenues and other income	90,924	45,818	64,357
Purchases (net of inventory variation)	(35,160)	(20,986)	(29,532)
Operating, selling, general and administrative expenses	(9,378)	(9,537)	(10,469)
Depreciation, amortisation and net impairment losses	(11,719)	(15,235)	(13,204)
Exploration expenses	(1,004)	(3,483)	(1,854)
Total Operating expenses	(57,261)	(49,241)	(55,058)
Net operating income/(loss)	33,663	(3,423)	9,299
Additions to PP&E, intangibles and equity accounted investments	8,506	9,762	14,782
Balance sheet information [abstract]
Equity accounted investments	2,686	2,262	1,442
Noncurrent Assets	84,618	92,623	95,083
Unallocated amounts [member]
Balance sheet information [abstract]
Noncurrent Assets	13,406	13,704	11,152
Segments [member]
Balance sheet information [abstract]
Noncurrent Assets	68,527	76,657	82,489
Segments [member] | E&P- Norway [member]
Disclosure of operating segments [line items]
Revenues third party, other revenues and other income	269	91	1,048
Revenues inter-segment	38,972	11,804	17,769
Net income/(loss) from equity accounted investments	0	0	15
Total revenues and other income	39,241	11,895	18,832
Purchases (net of inventory variation)	0	0	(1)
Operating, selling, general and administrative expenses	(3,729)	(2,829)	(3,284)
Depreciation, amortisation and net impairment losses	(4,678)	(5,546)	(5,439)
Exploration expenses	(363)	(423)	(478)
Total Operating expenses	(8,770)	(8,798)	(9,201)
Net operating income/(loss)	30,471	3,097	9,631
Additions to PP&E, intangibles and equity accounted investments	5,101	4,851	7,316
Balance sheet information [abstract]
Equity accounted investments	3	3	3
Noncurrent Assets	35,301	37,733	34,938
Segments [member] | E&P International [member]
Disclosure of operating segments [line items]
Revenues third party, other revenues and other income	1,113	451	1,685
Revenues inter-segment	4,230	3,183	4,376
Net income/(loss) from equity accounted investments	214	(146)	24
Total revenues and other income	5,558	3,489	6,085
Purchases (net of inventory variation)	(58)	(72)	(34)
Operating, selling, general and administrative expenses	(1,466)	(1,439)	(1,684)
Depreciation, amortisation and net impairment losses	(3,257)	(3,471)	(2,228)
Exploration expenses	(451)	(2,071)	(668)
Total Operating expenses	(5,232)	(7,054)	(4,614)
Net operating income/(loss)	326	(3,565)	1,471
Additions to PP&E, intangibles and equity accounted investments	1,828	2,609	2,851
Balance sheet information [abstract]
Equity accounted investments	1,417	1,125	321
Noncurrent Assets	15,358	17,835	21,161
Segments [member] | E&P USA [member]
Disclosure of operating segments [line items]
Revenues third party, other revenues and other income	377	368	441
Revenues inter-segment	3,771	2,247	3,792
Net income/(loss) from equity accounted investments	0	0	6
Total revenues and other income	4,149	2,615	4,239
Purchases (net of inventory variation)	0	0	0
Operating, selling, general and administrative expenses	(1,076)	(1,313)	(1,668)
Depreciation, amortisation and net impairment losses	(1,733)	(3,824)	(4,133)
Exploration expenses	(190)	(990)	(709)
Total Operating expenses	(2,999)	(6,127)	(6,510)
Net operating income/(loss)	1,150	(3,512)	(2,271)
Additions to PP&E, intangibles and equity accounted investments	690	1,068	3,004
Balance sheet information [abstract]
Equity accounted investments	0	0	0
Noncurrent Assets	11,406	12,586	16,929
Segments [member] | MMP [member]
Disclosure of operating segments [line items]
Revenues third party, other revenues and other income	87,025	44,605	60,491
Revenues inter-segment	321	309	439
Net income/(loss) from equity accounted investments	22	31	25
Total revenues and other income	87,368	44,945	60,955
Purchases (net of inventory variation)	(80,873)	(38,072)	(54,454)
Operating, selling, general and administrative expenses	(4,276)	(5,060)	(4,897)
Depreciation, amortisation and net impairment losses	(1,079)	(1,453)	(600)
Exploration expenses	0	0	0
Total Operating expenses	(86,227)	(44,586)	(59,951)
Net operating income/(loss)	1,141	359	1,004
Additions to PP&E, intangibles and equity accounted investments	221	190	788
Balance sheet information [abstract]
Equity accounted investments	113	92	90
Noncurrent Assets	3,019	4,368	5,248
Segments [member] | REN [member]
Disclosure of operating segments [line items]
Revenues third party, other revenues and other income	1,394	18	258
Revenues inter-segment	0	0	0
Net income/(loss) from equity accounted investments	16	163	95
Total revenues and other income	1,411	181	353
Purchases (net of inventory variation)	0	0	0
Operating, selling, general and administrative expenses	(163)	(215)	(192)
Depreciation, amortisation and net impairment losses	(3)	(1)	(1)
Exploration expenses	0	0	0
Total Operating expenses	(166)	(216)	(193)
Net operating income/(loss)	1,245	(35)	160
Additions to PP&E, intangibles and equity accounted investments	455	31	175
Balance sheet information [abstract]
Equity accounted investments	1,108	1,017	1,003
Noncurrent Assets	154	3	187
Segments [member] | Other [member]
Disclosure of operating segments [line items]
Revenues third party, other revenues and other income	485	232	269
Revenues inter-segment	5	4	4
Net income/(loss) from equity accounted investments	7	5	(1)
Total revenues and other income	497	241	271
Purchases (net of inventory variation)	(1)	(1)	(1)
Operating, selling, general and administrative expenses	264	634	465
Depreciation, amortisation and net impairment losses	(970)	(939)	(803)
Exploration expenses	0	(1)	0
Total Operating expenses	(707)	(304)	(339)
Net operating income/(loss)	(210)	(63)	(68)
Additions to PP&E, intangibles and equity accounted investments	212	1,013	648
Balance sheet information [abstract]
Equity accounted investments	45	25	25
Noncurrent Assets	3,288	4,132	4,026
Eliminations [member]
Disclosure of operating segments [line items]
Revenues third party, other revenues and other income	0	0	0
Revenues inter-segment	(47,300)	(17,547)	(26,379)
Net income/(loss) from equity accounted investments	0	0	0
Total revenues and other income	(47,300)	(17,547)	(26,379)
Purchases (net of inventory variation)	45,773	17,157	24,958
Operating, selling, general and administrative expenses	1,066	685	793
Depreciation, amortisation and net impairment losses	0	0	0
Exploration expenses	0	0	0
Total Operating expenses	46,839	17,842	25,750
Net operating income/(loss)	(461)	296	(629)
Additions to PP&E, intangibles and equity accounted investments	0	0	0
Balance sheet information [abstract]
Equity accounted investments	0	0	0
Noncurrent Assets	$ 0	$ 0	$ 0

Segments - Non current assets b

Segments - Non current assets by country (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)Countries	Dec. 31, 2020USD ($)	Dec. 31, 2019
Disclosure of geographical areas [line items]
Non-current assets	$ 71,213	$ 78,919
Minimum [member]
Disclosure of geographical areas [line items]
Number of countries with operating units | Countries	30
Norway [member]
Disclosure of geographical areas [line items]
Non-current assets	$ 40,564	$ 44,311
Percentage of entity's revenue	81.00%	80.00%	75.00%
USA [member]
Disclosure of geographical areas [line items]
Non-current assets	$ 12,323	$ 13,383
Percentage of entity's revenue	13.00%	14.00%	18.00%
Brazil [member]
Disclosure of geographical areas [line items]
Non-current assets	$ 8,751	$ 8,359
UK [member]
Disclosure of geographical areas [line items]
Non-current assets	2,096	4,491
Azerbaijan [member]
Disclosure of geographical areas [line items]
Non-current assets	1,654	1,708
Canada [member]
Disclosure of geographical areas [line items]
Non-current assets	1,403	1,584
Russia [member]
Disclosure of geographical areas [line items]
Non-current assets	1,235	973
Denmark [member]
Disclosure of geographical areas [line items]
Non-current assets	536	953
Algeria [member]
Disclosure of geographical areas [line items]
Non-current assets	708	808
Angola [member]
Disclosure of geographical areas [line items]
Non-current assets	948	883
Other countries [Member]
Disclosure of geographical areas [line items]
Non-current assets	$ 996	$ 1,465

Segments - Revenues from contra

Segments - Revenues from contracts with customers and other revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of geographical areas [line items]
Revenues from contracts with customers	$ 88,247	$ 45,088	$ 62,657
Taxes paid in kind	345	93	344
Physically settled commodity derivatives	(1,075)	209	(1,086)
Gain (loss) on commodity derivatives	951	108	732
Other revenues	276	256	265
Total other revenues	497	665	254
Revenues	88,744	45,753	62,911
Crude oil [member]
Disclosure of geographical areas [line items]
Revenues from contracts with customers	38,307	24,509	33,505
Natural gas [Member]
Disclosure of geographical areas [line items]
Revenues from contracts with customers	28,050	7,213	11,281
Natural gas [Member] | European [member]
Disclosure of geographical areas [line items]
Revenues from contracts with customers	24,900	5,839	9,366
Natural gas [Member] | North America [member]
Disclosure of geographical areas [line items]
Revenues from contracts with customers	1,783	1,010	1,359
Natural gas [Member] | Other incl LNG [member]
Disclosure of geographical areas [line items]
Revenues from contracts with customers	1,368	363	556
Refined products [Member]
Disclosure of geographical areas [line items]
Revenues from contracts with customers	11,473	6,534	10,652
Natural gas liquids [Member]
Disclosure of geographical areas [line items]
Revenues from contracts with customers	8,490	5,069	5,807
Trasnsportation [Member]
Disclosure of geographical areas [line items]
Revenues from contracts with customers	921	1,083	967
Other sales [member]
Disclosure of geographical areas [line items]
Revenues from contracts with customers	$ 1,006	$ 681	$ 445

Acquisitions and disposals - ac

Acquisitions and disposals - acquisitions (Details) € in Millions, $ in Millions	May 05, 2021USD ($)	Jun. 30, 2020USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2021USD ($)	May 05, 2021EUR (€)	May 05, 2021USD ($)
Wento [Member] | REN [member]
Acquisitions [line items]
Percentage of share acquired					100.00%	100.00%
Cash consideration					€ 98	$ 117
Acquired a receivable						3
Increase intangible assets as of acquisition date						46
Goodwill	$ 59
Increase in deferred tax liability						9
Increase in other assets						$ 21
KrasGeoNaC [member] | E&P International [member]
Acquisitions [line items]
Percentage of share acquired				49.00%
Total purchase price				$ 529
Cash consideration				384
Contingent payments				$ 145
SPM Argentina S.A. [member] | Bandurria Sur [Member]
Acquisitions [line items]
Ownership interest in joint venture			49.00%
SPM Argentina S.A. [member] | Shell [Member]
Acquisitions [line items]
Percentage of share acquired			50.00%
SPM Argentina S.A. [member] | E&P International [member]
Acquisitions [line items]
Percentage of share acquired			50.00%
Total purchase price			$ 187
Bandurria Sur Ownership [member] | E&P International [member]
Acquisitions [line items]
Percentage of share acquired		5.50%
Total purchase price		$ 44
Ownership interest in associate		30.00%

Acquisitions and disposals - di

Acquisitions and disposals - divestitures (Details) £ in Millions, kr in Billions

Feb. 10, 2022GBP (£)

Feb. 10, 2022USD ($)

Sep. 08, 2021

Feb. 26, 2021GBP (£)

Feb. 26, 2021USD ($)

Jan. 29, 2021USD ($)

Dec. 31, 2021USD ($)

Dec. 31, 2020USD ($)

Jun. 30, 2020SEK (kr)

Jun. 30, 2020USD ($)

Dec. 31, 2021USD ($)

Dec. 31, 2020USD ($)

Dec. 31, 2019USD ($)

Apr. 26, 2021USD ($)

Divestments [Line Items]

Exploration expenses

$ 1,004,000,000

$ 3,483,000,000

$ 1,854,000,000

Net income/(loss) from equity accounted investments

259,000,000

$ 53,000,000

$ 164,000,000

Corrib gas project in Ireland [Member]

Divestments [Line Items]

Consideration receivable from sale of equity interest

$ 434,000,000

$ 434,000,000

Equinor Energy Ireland [member] | Corrib gas project in Ireland, joint operations [Member]

Divestments [Line Items]

Proportion of voting rights held in joint operation

36.50%

Equinor Energy Ireland [member] | Corrib gas project in Ireland [Member]

Divestments [Line Items]

Proportion of ownership interest divested

100.00%

Vermilion [Member] | Corrib gas project in Ireland, joint operations [Member]

Divestments [Line Items]

Proportion of voting rights held in joint operation

20.00%

Nephin Energy [Member] | Corrib gas project in Ireland, joint operations [Member]

Divestments [Line Items]

Proportion of voting rights held in joint operation

43.50%

Dogger Bank Farm C [Member] | Other disposals of assets [member]

Divestments [Line Items]

Proportion of voting rights held in joint operation

40.00%

40.00%

Dogger Bank Farm C [Member] | SSE [Member] | Other disposals of assets [member]

Divestments [Line Items]

Proportion of voting rights held in joint operation

40.00%

40.00%

Dogger Bank Farm C [Member] | ENI [Member] | Other disposals of assets [member]

Divestments [Line Items]

Proportion of voting rights held in joint operation

20.00%

20.00%

Dogger Bank Farm C [Member] | Renewables [member] | Other disposals of assets [member]

Divestments [Line Items]

Proportion of ownership interest divested

10.00%

10.00%

Proceeds from divesture/sale

£ 68

$ 92,000,000

Equinor Refining Denmark A/S [Member]

Divestments [Line Items]

Proportion of ownership interest divested

100.00%

Proceeds from divesture/sale

$ 48,000,000

Proceeds from extraordinary dividend and repayment of paid-in capital

335,000,000

Equinor Refining Denmark A/S [Member] | MMP [member]

Divestments [Line Items]

Gain (loss) on disposal of assets or discontinued operations

167,000,000

Terra Nova [Member] | E&P International [member]

Divestments [Line Items]

Proportion of ownership interest divested

100.00%

Bakken onshore unconventional field [Member] | E&P USA [member]

Divestments [Line Items]

Potential consideration from divestment

$ 819,000,000

Dogger Bank Wind Farm A and B [member]

Divestments [Line Items]

Proportion of ownership interest divested

10.00%

10.00%

Proportion of ownership interest in associate

40.00%

40.00%

Proceeds from divesture/sale

£ 206.4

$ 285,000,000

Dogger Bank Wind Farm A and B [member] | SSE [Member]

Divestments [Line Items]

Proportion of ownership interest in associate

40.00%

40.00%

Dogger Bank Wind Farm A and B [member] | ENI [Member]

Divestments [Line Items]

Proportion of ownership interest in associate

20.00%

20.00%

Dogger Bank Wind Farm A and B [member] | Renewables [member]

Divestments [Line Items]

Gain (loss) on disposal of assets or discontinued operations

£ 202.8

$ 280,000,000

Empire Wind and Beacon Wind assets [member]

Divestments [Line Items]

Proportion of ownership interest divested

50.00%

Ownership interest in joint venture

50.00%

Total consideration after adjustments

$ 1,200,000,000

Prepaid

500,000,000

Empire Wind and Beacon Wind assets [member] | Renewables [member]

Divestments [Line Items]

Gain (loss) on disposal of assets or discontinued operations

$ 1,100,000,000

Divestment of Lundin Petroleum AB shares [Member]

Divestments [Line Items]

Proportion of ownership interest divested

4.90%

4.90%

Gain (loss) on disposal of assets or discontinued operations

$ (100,000,000)

Proceeds from divesture/sale

kr 3.3

$ 300,000,000

Sea of Okhotsk [Member] | E&P International [member]

Divestments [Line Items]

Exploration obligations outstanding

$ 0

$ 0

Exploration expenses

$ 166,000,000

Financial risk and capital ma_3

Financial risk and capital management - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)Core_Banks	Dec. 31, 2020USD ($)
Disclosure of offsetting of financial assets [line items]
Lease Liabilities	$ 3,562	$ 4,405
Statoil's Captive Insurance Company [Member]
Disclosure of offsetting of financial assets [line items]
Cash held as collateral	2,369	627
Liquidity risk [member]
Disclosure of offsetting of financial assets [line items]
Commercial Papers Programme	5,000
Revolving credit facility	$ 6,000
Number of banks | Core_Banks	19
Credit facility maturity date	maturing in 2024
Description of strategy for managing liquidity risk	Equinor raises debt in all major capital markets (USA, Europe and Asia) for long-term funding purposes. The policy is to have a maturity profile with repayments not exceeding 5% of capital employed in any year for the nearest five years.
Maximum Percentage Of Repayment Of Long Term Funding	5.00%
Maturity Profile Of Debt Funding Repayment	5 years
Non-current liabilities weighted average maturity	10 years
Credit risk [member]
Disclosure of offsetting of financial assets [line items]
Cash held as collateral	$ 2,271	1,704
Liabilities not offsetting under netting arrangements	500	387
Financial instruments offset under netting arrangements	$ 24,536	3,738
Trade and other receivables [member] | Credit risk [member]
Disclosure of offsetting of financial assets [line items]
Percentage of overdue trade and other receivables for 30 days and more	1.00%
Financial instruments offset under netting arrangements	$ 4,445	$ 1,684

Financial risk and capital ma_4

Financial risk and capital management - Undiscounted contractual cash flows (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Disclosure of maturity analysis for derivative financial liabilities [line items]
Non-derivative financial liabilities	$ 55,150	$ 52,421
Lease liabilities	3,901	4,504
Derivative financial liabilities	1,479	2,294
Year 1 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Non-derivative financial liabilities	18,841	13,388
Lease liabilities	1,183	1,220
Derivative financial liabilities	175	1,262
Year 2 and 3 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Non-derivative financial liabilities	6,684	5,528
Lease liabilities	1,262	1,598
Derivative financial liabilities	211	75
Year 4 and 5 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Non-derivative financial liabilities	6,140	6,489
Lease liabilities	656	772
Derivative financial liabilities	318	264
Year 6 to 10 [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Non-derivative financial liabilities	10,636	12,401
Lease liabilities	642	752
Derivative financial liabilities	588	269
After 10 years [member]
Disclosure of maturity analysis for derivative financial liabilities [line items]
Non-derivative financial liabilities	12,849	14,614
Lease liabilities	158	162
Derivative financial liabilities	$ 187	$ 425

Financial risk and capital ma_5

Financial risk and capital management - Credit risk exposure and grading (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Disclosure of internal credit grades [line items]
Description of internal credit ratings process	Prior to entering into transactions with new counterparties, Equinor’s credit policy requires all counterparties to be formally identified and assigned internal credit ratings. The internal credit ratings reflect Equinor’s assessment of the counterparties' credit risk and are based on a quantitative and qualitative analysis of recent financial statements and other relevant business. All counterparties are re-assessed regularly.
Non-current financial receivable [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	$ 708	$ 497
Trade and other receivables [member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	17,191	7,418
Non-current derivative financial instruments [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	1,265	2,476
Current derivative financial instrument [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	5,131	886
Investment grade, rated A or above [Member] | Non-current financial receivable [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	452	211
Investment grade, rated A or above [Member] | Trade and other receivables [member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	3,637	1,954
Investment grade, rated A or above [Member] | Non-current derivative financial instruments [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	1,103	1,850
Investment grade, rated A or above [Member] | Current derivative financial instrument [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	2,902	465
Other investment grade [Member] | Non-current financial receivable [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	18	24
Other investment grade [Member] | Trade and other receivables [member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	8,930	2,288
Other investment grade [Member] | Non-current derivative financial instruments [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	0	478
Other investment grade [Member] | Current derivative financial instrument [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	1,524	287
Non-investment grade or not rated [Member] | Non-current financial receivable [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	238	262
Non-investment grade or not rated [Member] | Trade and other receivables [member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	4,624	3,176
Non-investment grade or not rated [Member] | Non-current derivative financial instruments [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	162	148
Non-investment grade or not rated [Member] | Current derivative financial instrument [Member]
Disclosure of internal credit grades [line items]
Financial assets subject to credit exposure	$ 705	$ 134

Financial risk and capital ma_6

Financial risk and capital management - Captial Management (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Capital management
Net interest-bearing debt adjusted, including lease liabilities (ND1)	$ 3,236	$ 20,121
Net interest-bearing debt adjusted (ND2)	(326)	15,716
Capital employed adjusted, including lease liabilities (CE1)	42,259	54,012
Capital employed adjusted (CE2)	$ 38,697	$ 49,608
Net debt to capital employed adjusted, including lease liabilities (ND1/CE1)	7.70%	37.30%
Net debt to capital employed adjusted (ND)/(CE)	(0.80%)	31.70%

Remuneration (Details)

Remuneration (Details)	12 Months Ended
	Dec. 31, 2021USD ($)Employees	Dec. 31, 2020USD ($)Employees	Dec. 31, 2019USD ($)Employees
Renumeration [abstract]
Salaries	$ 2,962,000,000	$ 2,625,000,000	$ 2,766,000,000
Pension costs	488,000,000	432,000,000	446,000,000
Payroll tax	414,000,000	368,000,000	413,000,000
Other compensations and social costs	288,000,000	283,000,000	330,000,000
Total payroll costs	$ 4,152,000,000	$ 3,707,000,000	$ 3,955,000,000
Average number of employees | Employees	21,400	21,700	21,400
Part time employees as percentage of total employees	3.00%	2.00%	4.00%
Remuneration to members of the BoD and the CEC [abstract]
Current employee benefits	$ 12,229,000,000	$ 9,012,000,000	$ 10,958,000,000
Post-employment benefits	420,000,000	589,000,000	661,000,000
Other non-current benefits	17,000,000	14,000,000	18,000,000
Share-based payment benefits	83,000,000	125,000,000	147,000,000
Total compensation expense	12,749,000,000	9,740,000,000	11,782,000,000
Loans to the members of the BoD or the CEC	0	$ 0	$ 0
Compensation cost yet to be expensed	174,000,000
2022 programme [member]
Disclosure of terms and conditions of share-based payment arrangement [line items]
Estimated compensation expense	85,000,000
2021 programme [member]
Disclosure of terms and conditions of share-based payment arrangement [line items]
Estimated compensation expense	79,000,000
2020 programme [member]
Disclosure of terms and conditions of share-based payment arrangement [line items]
Estimated compensation expense	74,000,000
2019 programme [member]
Disclosure of terms and conditions of share-based payment arrangement [line items]
Estimated compensation expense	$ 73,000,000

Other expenses (Details)

Other expenses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Auditor's remuneration [abstract]
Research and development expenditures	$ 291	$ 254	$ 300
Disclosure of operating segments [line items]
Total	15.5	11.7	10.3
KPMG [Member]
Disclosure of operating segments [line items]
Audit fee		0	2.8
Audit related fee		0	1.2
Tax fee		0	0
Other service fee		0	0
Ernst and Young [Member]
Disclosure of operating segments [line items]
Audit fee	14.4	10.7	4.7
Audit related fee	1.1	1	0.5
Tax fee	0	0	0.2
Other service fee	0	0	0.9
Statoil operated licences [Member]
Disclosure of operating segments [line items]
The audit fees and audit related fees	$ 0.5	$ 0.5	$ 0.5

Financial items (Details)

Financial items (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Finance Income Expense [Abstract]
Foreign exchange gains (losses) derivative financial instruments	$ 870	$ (1,288)	$ 132
Other foreign exchange gains (losses)	(823)	642	92
Net foreign exchange gains (losses)	47	(646)	224
Dividends received	39	44	75
Gains (losses) financial investments	(348)	456	243
Interest income on other financial assets	38	108	125
Interest income non-current financial receivables	26	34	21
Interest income current financial assets and other financial items	48	113	281
Interest income and other financial items	151	298	502
Gains (losses) derivative financial instruments	(708)	448	473
Interest expense bonds and bank loans and net interest on related derivatives	(896)	(951)	(987)
Interest expense lease liabilities	(93)	(104)	(126)
Capitalised borrowing costs	334	308	480
Accretion expense asset retirement obligations	(453)	(412)	(456)
Interest expense current financial liabilities and other finance expense	(114)	(232)	(360)
Interest and other finance expenses	(1,223)	(1,392)	(1,450)
Net financial items	(2,080)	(836)	(7)
Interest expense from the financial liabilities at amortised cost category	990	1,031	861
Net interest expense, fair value through profit or loss category		79	129
Net interest income, fair value through profit or loss category	94
Fair value gain (loss) from the trading instruments held	(724)	432	457
Net foreign exchange gain		$ 796
Net foreign exchange loss	$ 702		$ 74

Income taxes - Significant comp

Income taxes - Significant components of income tax expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Major components of tax (expense) income [abstract]
Current income tax expense in respect of current year	$ (21,271)	$ (1,115)	$ (7,892)
Prior period adjustments	(28)	313	69
Current income tax expense	(21,299)	(802)	(7,822)
Origination and reversal of temporary differences	(1,778)	(648)	410
Recognition of previously unrecognised deferred tax assets	126	130	0
Change in tax regulations	4	(12)	(6)
Prior period adjustments	(60)	94	(23)
Deferred tax expense	(1,708)	(435)	381
Income tax expense	$ (23,007)	$ (1,237)	$ (7,441)

Income taxes - Reconciliation o

Income taxes - Reconciliation of statutory tax rate to effective tax rate (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reconciliation of accounting profit multiplied by applicable tax rates [abstract]
Income/(loss) before tax		$ 31,583	$ (4,259)	$ 9,292
Calculated income tax at statutory rate		(7,053)	1,445	(2,284)
Calculated Norwegian Petroleum tax		(17,619)	(2,126)	(5,499)
Tax effect uplift		914	1,006	632
Tax effect of permanent differences regarding divestments		90	(9)	380
Tax effect of permanent differences caused by functional currency different from tax currency		150	(198)	8
Tax effect of other permanent differences		228	450	395
Recognition of previously unrecognised deferred tax assets		126	130	0
Change in unrecognised deferred tax assets		619	(1,685)	(974)
Change in tax regulations		4	(12)	(6)
Prior period adjustments		(88)	408	47
Other items including currency effects		(378)	(647)	(139)
Income tax expense		$ (23,007)	$ (1,237)	$ (7,441)
Effective tax rate		72.80%	(29.00%)	80.10%
Statutory tax rate		22.30%	33.90%	24.60%
Allowable uplift rate over a period of four years		5.20%
Unrecognised uplift credits		$ 272	$ 836
Uplift rate, for investments subject to transitional rules		7.50%
Uplift rate		24.00%	5.20%	5.30%
Norway [member]
Reconciliation of accounting profit multiplied by applicable tax rates [abstract]
Petroleum tax rate	(56.00%)	56.00%	56.00%
Minimum [member]
Reconciliation of accounting profit multiplied by applicable tax rates [abstract]
Uplift rate		20.80%
Minimum [member] | ForeignCountriesMember
Reconciliation of accounting profit multiplied by applicable tax rates [abstract]
Statutory tax rate		22.00%

Income taxes - Deferred tax ass

Income taxes - Deferred tax assets and liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Deferred tax assets and liabilities [abstract]
Deferred tax assets	$ 21,484	$ 22,966
Deferred tax liabilities	(29,140)	(29,217)
Net asset (liability)	(7,655)	(6,250)	$ (5,530)	$ (5,367)
Tax losses carried forward [member]
Deferred tax assets and liabilities [abstract]
Deferred tax assets	5,162	4,676
Deferred tax liabilities	0	0
Net asset (liability)	5,162	4,676
Property, plant and equipment and intangible assets [Member]
Deferred tax assets and liabilities [abstract]
Deferred tax assets	719	826
Deferred tax liabilities	(27,136)	(28,290)
Net asset (liability)	(26,417)	(27,464)
Property, plant and equipment and intangible assets [Member] | Impact of ARO policy change [member]
Deferred tax assets and liabilities [abstract]
Net asset (liability)		(1,762)
Asset retirement obligation [member]
Deferred tax assets and liabilities [abstract]
Deferred tax assets	11,256	12,967
Deferred tax liabilities	0	0
Net asset (liability)	11,256	12,967
Asset retirement obligation [member] | Impact of ARO policy change [member]
Deferred tax assets and liabilities [abstract]
Net asset (liability)		(1,762)
Lease liabilities [member]
Deferred tax assets and liabilities [abstract]
Deferred tax assets	1,506	1,869
Deferred tax liabilities	0	(4)
Net asset (liability)	1,506	1,865
Pensions [member]
Deferred tax assets and liabilities [abstract]
Deferred tax assets	804	787
Deferred tax liabilities	(21)	(11)
Net asset (liability)	783	777
Derivatives [member]
Deferred tax assets and liabilities [abstract]
Deferred tax assets	21	30
Deferred tax liabilities	(1,453)	(236)
Net asset (liability)	(1,432)	(206)
Other [Member]
Deferred tax assets and liabilities [abstract]
Deferred tax assets	2,015	1,811
Deferred tax liabilities	(530)	(676)
Net asset (liability)	$ 1,485	$ 1,135

Income taxes - Changes in Defer

Income taxes - Changes in Deferred tax assets and liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Changes in net deferred tax liability during the year [abstract]
Net deferred tax liability beginning balance	$ 6,250	$ 5,530	$ 5,367
Charged (credited) to the Consolidated statement of income	1,708	435	(381)
Charged (credited) to Other comprehensive income	35	(19)	98
Foreign currency translation effects and other effects	(337)	304	446
Net deferred tax liability ending balance	7,655	6,250	5,530
Net deferred tax assets and liabilities [abstract]
Deferred tax assets	6,259	4,974	3,881
Deferred tax liabilities	14,037	11,224	$ 9,410
Deferred tax assets recognized in entities which have suffered a loss in either the current or preceding period	4,636	2,328
Deferred tax assets	6,381
Deferred tax assets reported in Assets classified as held for sale	$ 122	$ 0

Income taxes - Unrecognised def

Income taxes - Unrecognised deferred tax assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Disclosure of temporary difference, unused tax losses and unused tax credits [line items]
Deductible temporary differences, basis	$ 2,900	$ 2,866
Unused tax credits, basis	0	0
Tax losses carried forward, basis	20,552	23,434
Total unrecognised deferred tax assets, basis	23,452	26,300
Deductible temporary differences, unrecognised deferred tax asset	1,203	1,204
Unused tax credits	264	212
Tax losses carried forward, unrecognised deferred tax asset	5,047	5,677
Total unrecognised deferred tax assets	$ 6,514	7,093
Percentage of unrecognised tax losses that can be carried forward indefinitely	22.00%
Remaining unrecognised tax losses expiry date	after 2032
United States [member]
Disclosure of temporary difference, unused tax losses and unused tax credits [line items]
Total unrecognised deferred tax assets	$ 4,206	4,649
Angola [member]
Disclosure of temporary difference, unused tax losses and unused tax credits [line items]
Total unrecognised deferred tax assets	$ 749	$ 740

Property, plant and equipment_2

Property, plant and equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	$ 68,508	$ 71,751
Property plant and equipment ending	62,075	68,508
Assets transferred to Property, plant and equipment from Intangible assets	1,730	89
Cost [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	215,587	209,221
Additions through business combinations	4
Additions and transfers	7,225	11,433
Disposals at cost	(4,420)	(295)
Assets reclassified to held for sale	(1,664)	(9,335)
Effect of changes in foreign exchange	(4,497)	4,563
Property plant and equipment ending	212,234	215,587
Cost [member] | As reported [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	212,751	207,422
Property plant and equipment ending		212,751
Cost [member] | Impact of policy change [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	2,836	1,799
Property plant and equipment ending		2,836
Cost [member] | As restated [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	215,587
Property plant and equipment ending		215,587
Accumulated depreciation, amortisation and impairment [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	(147,079)	(137,469)
Assets reclassified to held for sale	1,367	8,525
Depreciation	(10,408)	(9,488)
Impairment losses	(2,962)	(5,889)
Reversal of impairment losses	1,677	218
Transfers	(11)	(10)
Accumulated depreciation and impairment disposed assets	4,118	278
Effect of changes in foreign exchange	3,138	(3,244)
Property plant and equipment ending	(150,159)	(147,079)
Machinery, equipment and transportation equipment [Member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	209
Property plant and equipment ending	$ 147	$ 209
Machinery, equipment and transportation equipment [Member] | Maximum [member]
Disclosure of detailed information about property, plant and equipment [line items]
Estimated useful lives (years)	20 years	20 years
Machinery, equipment and transportation equipment [Member] | Minimum [member]
Disclosure of detailed information about property, plant and equipment [line items]
Estimated useful lives (years)	3 years	3 years
Machinery, equipment and transportation equipment [Member] | Cost [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	$ 2,806	$ 2,818
Additions through business combinations	0
Additions and transfers	39	68
Disposals at cost	(1,496)	(28)
Assets reclassified to held for sale	0	(66)
Effect of changes in foreign exchange	(13)	13
Property plant and equipment ending	1,335	2,806
Machinery, equipment and transportation equipment [Member] | Cost [member] | As reported [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	2,806	2,818
Property plant and equipment ending		2,806
Machinery, equipment and transportation equipment [Member] | Cost [member] | Impact of policy change [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	0	0
Property plant and equipment ending		0
Machinery, equipment and transportation equipment [Member] | Cost [member] | As restated [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	2,806
Property plant and equipment ending		2,806
Machinery, equipment and transportation equipment [Member] | Accumulated depreciation, amortisation and impairment [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	(2,596)	(2,395)
Assets reclassified to held for sale	0	65
Depreciation	(68)	(102)
Impairment losses	(42)	(201)
Reversal of impairment losses	0	0
Transfers	61	18
Accumulated depreciation and impairment disposed assets	1,448	27
Effect of changes in foreign exchange	9	(9)
Property plant and equipment ending	(1,188)	(2,596)
Production plants and oil and gas assets [Member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	50,654
Property plant and equipment ending	45,595	50,654
Production plants and oil and gas assets [Member] | Cost [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	183,082	180,825
Additions through business combinations	2
Additions and transfers	7,311	7,782
Disposals at cost	(1,975)	(243)
Assets reclassified to held for sale	(1,010)	(9,095)
Effect of changes in foreign exchange	(4,052)	3,812
Property plant and equipment ending	183,358	183,082
Production plants and oil and gas assets [Member] | Cost [member] | As reported [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	180,355	179,063
Property plant and equipment ending		180,355
Production plants and oil and gas assets [Member] | Cost [member] | Impact of policy change [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	2,726	1,762
Property plant and equipment ending		2,726
Production plants and oil and gas assets [Member] | Cost [member] | As restated [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	183,082
Property plant and equipment ending		183,082
Production plants and oil and gas assets [Member] | Accumulated depreciation, amortisation and impairment [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	(132,427)	(125,327)
Assets reclassified to held for sale	825	8,373
Depreciation	(9,136)	(8,240)
Impairment losses	(2,092)	(4,667)
Reversal of impairment losses	1,675	218
Transfers	(1,319)	(68)
Accumulated depreciation and impairment disposed assets	1,785	231
Effect of changes in foreign exchange	2,926	(2,947)
Property plant and equipment ending	(137,763)	(132,427)
Refining and manufacturing plants [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	1,232
Property plant and equipment ending	$ 555	$ 1,232
Refining and manufacturing plants [member] | Maximum [member]
Disclosure of detailed information about property, plant and equipment [line items]
Estimated useful lives (years)	20 years	20 years
Refining and manufacturing plants [member] | Minimum [member]
Disclosure of detailed information about property, plant and equipment [line items]
Estimated useful lives (years)	15 years	15 years
Refining and manufacturing plants [member] | Cost [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	$ 9,238	$ 8,920
Additions through business combinations	0
Additions and transfers	95	110
Disposals at cost	(70)	(7)
Assets reclassified to held for sale	(563)	0
Effect of changes in foreign exchange	(220)	214
Property plant and equipment ending	8,481	9,238
Refining and manufacturing plants [member] | Cost [member] | As reported [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	9,238	8,920
Property plant and equipment ending		9,238
Refining and manufacturing plants [member] | Cost [member] | Impact of policy change [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	0	0
Property plant and equipment ending		0
Refining and manufacturing plants [member] | Cost [member] | As restated [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	9,238
Property plant and equipment ending		9,238
Refining and manufacturing plants [member] | Accumulated depreciation, amortisation and impairment [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	(8,005)	(7,051)
Assets reclassified to held for sale	461	0
Depreciation	(232)	(248)
Impairment losses	(401)	(516)
Reversal of impairment losses	0	0
Transfers	0	(1)
Accumulated depreciation and impairment disposed assets	59	7
Effect of changes in foreign exchange	192	(196)
Property plant and equipment ending	(7,926)	(8,005)
Buildings and land [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	405
Property plant and equipment ending	$ 276	$ 405
Buildings and land [member] | Maximum [member]
Disclosure of detailed information about property, plant and equipment [line items]
Estimated useful lives (years)	33 years	33 years
Buildings and land [member] | Minimum [member]
Disclosure of detailed information about property, plant and equipment [line items]
Estimated useful lives (years)	10 years	20 years
Buildings and land [member] | Cost [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	$ 929	$ 909
Additions through business combinations	0
Additions and transfers	27	27
Disposals at cost	(353)	0
Assets reclassified to held for sale	0	(15)
Effect of changes in foreign exchange	(6)	7
Property plant and equipment ending	596	929
Buildings and land [member] | Cost [member] | As reported [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	929	909
Property plant and equipment ending		929
Buildings and land [member] | Cost [member] | Impact of policy change [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	0	0
Property plant and equipment ending		0
Buildings and land [member] | Cost [member] | As restated [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	929
Property plant and equipment ending		929
Buildings and land [member] | Accumulated depreciation, amortisation and impairment [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	(524)	(475)
Assets reclassified to held for sale	0	12
Depreciation	(42)	(23)
Impairment losses	(21)	(36)
Reversal of impairment losses	0	0
Transfers	(61)	0
Accumulated depreciation and impairment disposed assets	326	0
Effect of changes in foreign exchange	2	(3)
Property plant and equipment ending	(320)	(524)
Assets under development [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	11,888
Property plant and equipment ending	12,270	11,888
Assets under development [member] | Cost [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	13,163	10,408
Additions through business combinations	1
Additions and transfers	(396)	2,478
Disposals at cost	(25)	(5)
Assets reclassified to held for sale	0	(159)
Effect of changes in foreign exchange	(130)	441
Property plant and equipment ending	12,614	13,163
Assets under development [member] | Cost [member] | As reported [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	13,053	10,371
Property plant and equipment ending		13,053
Assets under development [member] | Cost [member] | Impact of policy change [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	110	37
Property plant and equipment ending		110
Assets under development [member] | Cost [member] | As restated [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	13,163
Property plant and equipment ending		13,163
Assets under development [member] | Accumulated depreciation, amortisation and impairment [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	(1,275)	(892)
Assets reclassified to held for sale	0	75
Depreciation	0	0
Impairment losses	(390)	(445)
Reversal of impairment losses	0	0
Transfers	1,319	41
Accumulated depreciation and impairment disposed assets	21	1
Effect of changes in foreign exchange	(18)	(56)
Property plant and equipment ending	(344)	(1,275)
Right of use assets [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	4,119
Property plant and equipment ending	$ 3,231	$ 4,119
Right of use assets [member] | Maximum [member]
Disclosure of detailed information about property, plant and equipment [line items]
Estimated useful lives (years)	20 years	19 years
Right of use assets [member] | Minimum [member]
Disclosure of detailed information about property, plant and equipment [line items]
Estimated useful lives (years)	1 year	1 year
Right of use assets [member] | Cost [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	$ 6,370	$ 5,339
Additions through business combinations	0
Additions and transfers	148	968
Disposals at cost	(501)	(13)
Assets reclassified to held for sale	(91)	0
Effect of changes in foreign exchange	(77)	75
Property plant and equipment ending	5,850	6,370
Right of use assets [member] | Cost [member] | As reported [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	6,370	5,339
Property plant and equipment ending		6,370
Right of use assets [member] | Cost [member] | Impact of policy change [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	0	0
Property plant and equipment ending		0
Right of use assets [member] | Cost [member] | As restated [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	6,370
Property plant and equipment ending		6,370
Right of use assets [member] | Accumulated depreciation, amortisation and impairment [member]
Disclosure of detailed information about property, plant and equipment [line items]
Property plant and equipment beginning	(2,251)	(1,329)
Assets reclassified to held for sale	82	0
Depreciation	(930)	(874)
Impairment losses	(17)	(25)
Reversal of impairment losses	2	0
Transfers	(11)	0
Accumulated depreciation and impairment disposed assets	480	11
Effect of changes in foreign exchange	27	(35)
Property plant and equipment ending	$ (2,619)	$ (2,251)

Property, plant and equipment -

Property, plant and equipment -Impairments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	$ 1,439	$ 7,057	$ 4,093
The total net impairment losses recognised under IAS 36	1,285	6,401
Goodwill [member]
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	1	42	164
Other intangible assets [member]
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	0	8	41
Acquisition costs related to oil and gas prospects [member]
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	154	657	49
Producing and development assets [Member]
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	1,283	6,351	3,838
Property Plant And Equipment [member]
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	1,285	5,671	3,230
Property Plant And Equipment [member] | Producing and development assets [Member]
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	1,285	5,671	3,230
Intangible assets [member]
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	154	1,386	863
Intangible assets [member] | Goodwill [member]
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	1	42	164
Intangible assets [member] | Other intangible assets [member]
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	0	8	41
Intangible assets [member] | Acquisition costs related to oil and gas prospects [member]
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	154	657	49
Intangible assets [member] | Producing and development assets [Member]
Disclosure of impairment loss and reversal of impairment loss [line items]
Total net impairment loss/ (reversal) recognized	$ (2)	$ 680	$ 608

Property, plant and equipment_3

Property, plant and equipment -impairment of carrying amount of impaired asset (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Base discount rate for VIU calculations, net of tax	5.00%
Carrying amount after impairment	$ 10,610	$ 21,619
Net impairement loss (Reversal)	$ 1,282	6,351
Exploration and Production Norway [Member] | High range value [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Derived pretax Discount rate range	32.00%
Exploration and Production Norway [Member] | Low range value [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Derived pretax Discount rate range	18.00%
Exploration and Production International [Member] | High range value [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Derived pretax Discount rate range	9.00%
Exploration and Production International [Member] | Low range value [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Derived pretax Discount rate range	5.00%
Exploration And Production USA [Member] | High range value [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Derived pretax Discount rate range	7.00%
Exploration And Production USA [Member] | Low range value [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Derived pretax Discount rate range	6.00%
Marketing, Midstream and Processing (MMP) [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Derived pretax Discount rate range	7.00%
VIU [Member] | Right of use assets [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Carrying amount after impairment	$ 16	265
Net impairement loss (Reversal)	(2)	36
VIU [Member] | North America - offshore other areas [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Carrying amount after impairment	0	53
Net impairement loss (Reversal)	0	146
VIU [Member] | Europe and Asia [Member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Carrying amount after impairment	1,566	3,687
Net impairement loss (Reversal)	1,609	1,280
VIU [Member] | Exploration and Production Norway [Member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Carrying amount after impairment	5,379	7,042
Net impairement loss (Reversal)	(1,102)	1,219
VIU [Member] | Exploration And Production USA [Member] | Onshore [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Carrying amount after impairment	1,979	4,676
Net impairement loss (Reversal)	8	(19)
VIU [Member] | Exploration And Production USA [Member] | Offshore Gulf of Mexico [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Carrying amount after impairment	798	2,808
Net impairement loss (Reversal)	18	305
VIU [Member] | Marketing, Midstream and Processing (MMP) [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Carrying amount after impairment	632	1,297
Net impairement loss (Reversal)	486	824
FVLCOD [Member] | Right of use assets [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Carrying amount after impairment	4	0
Net impairement loss (Reversal)	17	0
FVLCOD [Member] | North America - offshore other areas [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Carrying amount after impairment	0	0
Net impairement loss (Reversal)	(22)	0
FVLCOD [Member] | Exploration And Production USA [Member] | Onshore [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Carrying amount after impairment	0	1,122
Net impairement loss (Reversal)	40	2,331
FVLCOD [Member] | Marketing, Midstream and Processing (MMP) [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Carrying amount after impairment	236	668
Net impairement loss (Reversal)	$ 230	$ 228

Property, plant and equipment_4

Property, plant and equipment -impairment (narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Net impairment loss	$ 1,439	$ 7,057	$ 4,093
Impairment reversals	1,102
Impairment loss	1,285	6,401
Exploration expenses	1,004	3,483	$ 1,854
E&P- Norway [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment loss		1,219
E&P International [member] | North America offshore other areas [Member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment reversals	22
Impairment loss		146
E&P International [member] | Europe and Asia [Member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Net impairment loss	1,609
Impairment loss		1,280
E&P International [member] | Europe and Asia [Member] | Downward reserve revision [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Net impairment loss	1,786
E&P International [member] | Europe and Asia [Member] | Higher prices [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Net impairment loss	177
E&P USA [member] | Onshore [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Net impairment loss	48	2,313
Impairment reversals	60	234
Impairment loss	108	2,547
Exploration expenses	2	680
E&P USA [member] | Onshore [member] | Price assumptions and change to fair value less cost of disposal valuation [Member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Exploration expenses		743
E&P USA [member] | Onshore [member] | Downward reserve revision [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Exploration expenses	20
E&P USA [member] | Onshore [member] | Upward reserve revision [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Exploration expenses	22
E&P USA [member] | Offshore Gulf of Mexico [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment loss	18	305
MMP [member]
Disclosure of information for impairment loss recognised or reversed for individual asset or cash-generating unit [line items]
Impairment loss	$ 716	$ 1,052

Property, plant and equipment_5

Property, plant and equipment -price assumptions (narrative) (Details) $ in Billions	3 Months Ended	12 Months Ended
	Sep. 30, 2021€ / MWh	Dec. 31, 2021USD ($)$ / bbl	Dec. 31, 2021USD ($)$ / MMBTU	Dec. 31, 2021USD ($)kr / $	Dec. 31, 2021USD ($)kr / €	Dec. 31, 2021USD ($)kr / t	Dec. 31, 2021USD ($)€ / t	Dec. 31, 2021USD ($)€ / MWh	Dec. 31, 2021USD ($)$ / £	Dec. 31, 2020$ / bbl$ / MMBTU€ / t€ / MWh
Price Assumptions Used For Impairment Calculations [Line Items]
Percentage of estimated decline in commodity prices		30.00%	30.00%	30.00%	30.00%	30.00%	30.00%	30.00%	30.00%
Weighted Average Cost of Capital		5.00%	5.00%	5.00%	5.00%	5.00%	5.00%	5.00%	5.00%
External carbon price | € / t										56
Impairment exposure due to net zero emission | $		$ 9	$ 9	$ 9	$ 9	$ 9	$ 9	$ 9	$ 9
2022 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Electricity price | € / MWh	77							157		61
2024 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Long-term exchange rates				8.50	10				1.35
2026 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
External carbon price | € / t							80
2030 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Electricity price | € / MWh								58		43
External carbon price | € / t							65			27.5
Expected tax increase on carbon emissions maximum | kr / t						2,000
2050 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
External carbon price | € / t							100			41
NBP Natural Gas Price [Member] | 2030 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Estimated crude oil or Gas price per unit			6.4							6.7
NBP Natural Gas Price [Member] | 2040 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Estimated crude oil or Gas price per unit			7.7							8
NBP Natural Gas Price [Member] | 2050 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Estimated crude oil or Gas price per unit			7							7.7
Henry Hub Natural Gas Price [Member] | 2030 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Estimated crude oil or Gas price per unit			3.2							3.3
Henry Hub Natural Gas Price [Member] | 2040 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Estimated crude oil or Gas price per unit			3.3							3.8
Brent Blend oil price [member] | 2025 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Estimated crude oil or Gas price per unit | $ / bbl		65								67
Brent Blend oil price [member] | 2040 [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Estimated crude oil or Gas price per unit | $ / bbl		64								66
Brent Blend oil price [member] | 2050 [member] | Maximum [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Estimated crude oil or Gas price per unit | $ / bbl		60

Intangible assets (Details)

Intangible assets (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		$ 8,149	$ 10,738
Expensed exploration expenditures previously capitalised		(171)	(2,506)	$ (777)
Intangibles ending	$ 8,149	6,452	8,149	10,738
Exploration And Production USA [Member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Net reversal of impairment loss		$ 2
Minimum [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangible assets with finite useful lives		3 years
Maximum [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangible assets with finite useful lives		20 years
Cost [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		$ 8,505	11,033
Additions through business combinations		116
Additions		262	492
Disposals at cost		(53)	(8)
Transfers		(1,730)	(89)
Expensed exploration expenditures previously capitalised		(171)	(2,506)
Impairment of goodwill		(1)	(42)
Assets reclassified to held for sale			(499)
Effect of changes in foreign exchange		(111)	123
Intangibles ending	8,505	6,816	8,505	11,033
Accumulated depreciation, amortisation and impairment [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		(356)	(295)
Amortisation and impairments for the year		(24)	(35)
Assets reclassified to held for sale			(17)
Amortisation and impairment losses disposed intangible assets		13	(6)
Effect of changes in foreign exchange		3	(3)
Intangibles ending	(356)	(364)	(356)	(295)
Exploration expenses [Member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		2,261
Intangibles ending	2,261	1,958	2,261
Impairments, intangible assets		154
Exploration expenses [Member] | Dry wells and uncommercial discoveries and unconventional onshore assets [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Impairments, intangible assets			657
Exploration expenses [Member] | Cost [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		2,261	3,014
Additions through business combinations		0
Additions		191	401
Disposals at cost		(22)	(7)
Transfers		(432)	(16)
Expensed exploration expenditures previously capitalised		(19)	(1,169)
Impairment of goodwill		0	0
Assets reclassified to held for sale			0
Effect of changes in foreign exchange		(21)	38
Intangibles ending	2,261	1,958	2,261	3,014
Acquisition costs related to oil and gas prospects [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		3,932
Intangibles ending	3,932	2,670	3,932
Impairments, intangible assets		152
Acquisition costs related to oil and gas prospects [member] | Cost [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		3,932	5,599
Additions through business combinations		0
Additions		36	67
Disposals at cost		1	0
Transfers		(1,137)	(73)
Expensed exploration expenditures previously capitalised		(152)	(1,337)
Impairment of goodwill		0	0
Assets reclassified to held for sale			(339)
Effect of changes in foreign exchange		(10)	16
Intangibles ending	3,932	2,670	3,932	5,599
Goodwill [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		1,481
Intangibles ending	1,481	1,467	1,481
Goodwill [member] | Cost [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		1,481	1,458
Additions through business combinations		61
Additions		0	0
Disposals at cost		(3)	0
Transfers		0	0
Expensed exploration expenditures previously capitalised		0	0
Impairment of goodwill		(1)	(42)
Assets reclassified to held for sale			0
Effect of changes in foreign exchange		(70)	64
Intangibles ending	1,481	1,467	1,481	1,458
Goodwill [member] | Cost [member] | Exploration and Production Norway [Member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Goodwill related to business acquired in 2019	615		615
Goodwill [member] | Cost [member] | Marketing, Midstream and Processing (MMP) [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Goodwill related to business acquired in 2019	435		435
Other intangible assets [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		475
Intangibles ending	475	358	475
Other intangible assets [member] | Cost [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		831	962
Additions through business combinations		55
Additions		35	24
Disposals at cost		(29)	0
Transfers		(161)	0
Expensed exploration expenditures previously capitalised		0	0
Impairment of goodwill		0	0
Assets reclassified to held for sale			(160)
Effect of changes in foreign exchange		(10)	6
Intangibles ending	831	722	831	962
Other intangible assets [member] | Accumulated depreciation, amortisation and impairment [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Intangibles beginning		(356)	(295)
Amortisation and impairments for the year		(24)	35
Assets reclassified to held for sale			(17)
Amortisation and impairment losses disposed intangible assets		13	(6)
Effect of changes in foreign exchange		3	(3)
Intangibles ending	(356)	$ (364)	(356)	$ (295)
Signature bonuses and acquisition costs [Member] | Unconventional assets [Member] | Exploration And Production USA [Member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Impairments, intangible assets			$ 680
Capitalised well costs [member] | Tanzania [member]
Disclosure of reconciliation of changes in intangible assets and goodwill [line items]
Impairments, intangible assets	$ 982

Intangible assets - Exploration

Intangible assets - Exploration expenditures (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of detailed information about intangible assets [line items]
Intangible exploration and evaluation assets	$ 1,958	$ 2,261
Exploration expenditures	1,027	1,371	$ 1,584
Expensed exploration expenditures previously capitalised	171	2,506	777
Capitalised exploration	(194)	(394)	(507)
Exploration expenses	1,004	3,483	$ 1,854
Less than one year [member]
Disclosure of detailed information about intangible assets [line items]
Intangible exploration and evaluation assets	234	604
Between one and five years [member]
Disclosure of detailed information about intangible assets [line items]
Intangible exploration and evaluation assets	692	623
More than five years [member]
Disclosure of detailed information about intangible assets [line items]
Intangible exploration and evaluation assets	$ 1,033	$ 1,033

Equity accounted investment - c

Equity accounted investment - continuity (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of associates [line items]
Net investment beginning	$ 2,270	$ 1,487
Net income/(loss) from equity accounted investments	259	53	$ 164
Acqusitions and increase in paid in capital	475	995
Dividends and other distributions	(230)	(141)
Other comprehensive income / (loss)	(58)	21
Divestments, derecognition and decrease in paid in capital	(31)	(147)
Net investment ending	2,686	2,270	1,487
Equity accounted investments	2,686	2,262	$ 1,442
Other equity accounted investments [Member]
Disclosure of associates [line items]
Net investment ending	750
Other long-term receivable in equity accounted investments	0	$ 8
Several investments [Member] | Maximum [member]
Disclosure of associates [line items]
Equity accounted investments	$ 750

Financial investments and fin_3

Financial investments and financial receivables (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of financial assets [line items]
Financial investments	$ 3,346	$ 4,083	$ 3,600
Prepayments and financial receivables	1,087	861	1,214
Financial investments	21,246	11,865	$ 7,426
Bond Investment [Member]
Disclosure of financial assets [line items]
Financial investments	1,822	1,866
Listed equity securities [member]
Disclosure of financial assets [line items]
Financial investments	778	1,648
Listed equity securities [member] | Scatec ASA [Member]
Disclosure of financial assets [line items]
Financial investments	360	831
Non-listed equity securities [member]
Disclosure of financial assets [line items]
Financial investments	746	569
Interest bearing financial receivables [member]
Disclosure of financial assets [line items]
Prepayments and financial receivables	707	465
Prepayments [Member]
Disclosure of financial assets [line items]
Prepayments and financial receivables	276	246
Other non-interest bearing receivables [Member]
Disclosure of financial assets [line items]
Prepayments and financial receivables	104	150
Time deposits [member]
Disclosure of financial assets [line items]
Financial investments	7,060	4,841
Interest bearing securities [Member]
Disclosure of financial assets [line items]
Financial investments	14,186	7,010
Listed Equity Securities [member]
Disclosure of financial assets [line items]
Financial investments	0	13
Investment portfolios [Member]
Disclosure of financial assets [line items]
Financial investments	$ 300	$ 202

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Inventories [abstract]
Crude oil	$ 2,014	$ 2,022
Petroleum products	315	443
Natural gas	642	229
Other	424	390
Inventories	3,395	3,084	$ 3,363
Inventory write-down	$ 77	$ 58

Trade and other receivables (De

Trade and other receivables (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Trade and other receivables [abstract]
Trade receivables from contracts with customers	$ 13,266	$ 5,729
Other current receivables	3,011	1,275
Joint venture receivables	491	340
Equity accounted investments and other related party receivables	423	74
Total financial trade and other receivables	17,191	7,418
Non-financial trade and other receivables	736	814
Trade and other receivables	$ 17,927	$ 8,232	$ 8,233

Cash and cash equivalents (Deta

Cash and cash equivalents (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash and cash equivalents [abstract]
Cash at bank available	$ 2,673	$ 1,648
Time deposits	1,906	1,132
Money Market Funds	2,714	492
Interest bearing securities	4,740	2,485
Disclosure of financial assets [line items]
Restricted cash, including margin deposits	2,093	999
Cash and cash equivalents	14,126	6,757	$ 5,177
Collateral deposits related to trading activities	$ 2,069	$ 425

Shareholders' equity and divi_3

Shareholders' equity and dividends - narrative (Details)	Feb. 08, 2022USD ($)$ / shares$ / bbl	Sep. 08, 2021USD ($)	Dec. 31, 2021USD ($)$ / shares	Dec. 31, 2020USD ($)$ / shares	Dec. 31, 2019USD ($)shares	Dec. 31, 2021NOK (kr)shares	Dec. 31, 2021USD ($)$ / sharesshares	Oct. 31, 2021USD ($)	Jul. 31, 2021USD ($)	Dec. 31, 2020NOK (kr)shares	Dec. 31, 2020USD ($)$ / sharesshares
Total number of shares issued | shares						3,257,687,707	3,257,687,707			3,257,687,707	3,257,687,707
Dividends declared per share | $ / shares			$ 0.6300	$ 0.5600
Increase (decrease) through treasury share transactions, equity			$ (429,000,000)	$ (890,000,000)	$ (500,000,000)
Proposal of dividend declaration [member]
Dividends declared per share | $ / shares	$ 0.20
Extraordinary dividend per share | $ / shares	$ 0.20
Minimum [member] | Share buy-back programme 2022 [member]
Percent of debt to capital employed	15.00%
Minimum [member] | Share buy-back programme 2022 [member] | Brent Blend oil price [member]
Estimated crude oil or Gas price per unit | $ / bbl	50
Maximum [member] | Share buy-back programme 2022 [member]
Percent of debt to capital employed	30.00%
Maximum [member] | Share buy-back programme 2022 [member] | Brent Blend oil price [member]
Estimated crude oil or Gas price per unit | $ / bbl	60
Norwegian State [Member] | Share buy-back programme 2022 [member]
Agreement to buy treasury shares	$ 1,000,000,000
Norwegian State [Member] | Maximum [member] | Share buy-back programme 2022 [member]
Agreement to buy treasury shares	$ 5,000,000,000
United States Dollar (USD) [Member]
Share capital							$ 1,163,987,792				$ 1,163,987,792
Norwegian kroner (NOK) [Member]
Share capital | kr						kr 8,144,219,267.50				kr 8,144,219,267.50
Nominal value per share | $ / shares							$ 2.50				$ 2.50
Treasury shares employees [member]
Treasury shares purchased			75,000,000	$ 68,000,000
Share buyback programme [member]
Number of shares outstanding | shares					23,578,410	13,460,292	13,460,292			0	0
Share buyback programme [member] | Third Party [Member]
Increase (decrease) through treasury share transactions, equity			$ 429,000,000
Share buyback programme [member] | Share-based Payment Arrangement, Tranche One [member]
Agreement to buy treasury shares							$ 600,000,000		$ 300,000,000
Share buyback programme [member] | Share-based Payment Arrangement, Tranche One [member] | Norwegian State [Member]
Agreement to buy treasury shares								$ 201,000,000
Share buyback programme [member] | Share-based Payment Arrangement, Tranche One [member] | Third Party [Member]
Treasury shares purchased		$ 99,000,000
Share buyback programme [member] | Share-based Payment Arrangement, Tranche One [member] | Third Party [Member] | Maximum [member]
Agreement to buy treasury shares								99,000,000
Share buyback programme [member] | Share Based Payment Arrangement Tranche Two [member] | Minimum [member]
Agreement to buy treasury shares								300,000,000
Share buyback programme [member] | Share Based Payment Arrangement Tranche Two [member] | Maximum [member]
Agreement to buy treasury shares								1,000,000,000
Share buyback programme [member] | Share Based Payment Arrangement Tranche Two [member] | Norwegian State [Member]
Agreement to buy treasury shares								670,000,000
Share buyback programme [member] | Share Based Payment Arrangement Tranche Two [member] | Third Party [Member]
Treasury shares purchased		232,000,000
Short-term obligation settled		222,000,000
Share buyback programme [member] | Share Based Payment Arrangement Tranche Two [member] | Third Party [Member] | Maximum [member]
Agreement to buy treasury shares		$ 330,000,000						$ 330,000,000

Shareholders' equity and divi_4

Shareholders' equity and dividends - dividends schedule (Details) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)$ / shares	Dec. 31, 2021USD ($)kr / shares	Dec. 31, 2020USD ($)$ / shares	Dec. 31, 2020USD ($)kr / shares
Dividends decared [abstract]
Dividends declared	$ 2,041	$ 2,041	$ 1,833	$ 1,833
Dividend per share | $ / shares	$ 0.6300		$ 0.5600
Dividends paid in cash	$ 1,797		$ 2,330
Dividends paid, ordinary shares per share | (per share)	$ 0.5600	$ 4.8078	$ 0.7100	$ 6.7583

Shareholders' equity and divi_5

Shareholders' equity and dividends - share buyback and treasury shares (Details) - shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Employees share saving plan [Member]
Share saving plan at 1 January	11,442,491	10,074,712
Purchase	3,412,994	4,604,106
Allocated to employees	(2,744,381)	(3,236,327)
Share saving plan at 31 December	12,111,104	11,442,491
Share buyback programme [member]
Share buy-back programme at 1 January	0	23,578,410
Purchase	13,460,292	3,142,849
Cancellation	0	(26,721,259)
Share buy-back programme at 31 December	13,460,292	0

Finance debt - Non-current fina

Finance debt - Non-current finance debt (Details) - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Disclosure of financial liabilities [line items]
Unsecured bonds	$ 27,568		$ 30,994
Unsecured loans	87		97
Total finance debt	27,655		31,091
Less current portion	250		1,974
Non-current finance debt	27,404	[1]	29,118	[1]	$ 21,754
United States Dollar (USD) [Member]
Disclosure of financial liabilities [line items]
Unsecured bonds	17,451		18,710
Euro (EUR) [Member]
Disclosure of financial liabilities [line items]
Unsecured bonds	7,925		10,057
Great Britain Pound (GBP) [Member]
Disclosure of financial liabilities [line items]
Unsecured bonds	1,852		1,877
Norwegian kroner (NOK) [Member]
Disclosure of financial liabilities [line items]
Unsecured bonds	$ 340		$ 352
Japanese yen (JPY) [Member]
Disclosure of financial liabilities [line items]
Weighted average interest rates	4.30%		4.30%
Unsecured loans	$ 87		$ 97
Fair value based on level 2 inputs [member]
Disclosure of financial liabilities [line items]
Unsecured bonds	31,237		36,359
Unsecured loans	106		119
Total finance debt	31,343		36,479
Less current portion	268		2,062
Non-current finance debt	31,075		34,417
Fair value based on level 2 inputs [member] | United States Dollar (USD) [Member]
Disclosure of financial liabilities [line items]
Unsecured bonds	19,655		21,883
Fair value based on level 2 inputs [member] | Euro (EUR) [Member]
Disclosure of financial liabilities [line items]
Unsecured bonds	8,529		11,115
Fair value based on level 2 inputs [member] | Great Britain Pound (GBP) [Member]
Disclosure of financial liabilities [line items]
Unsecured bonds	2,674		2,949
Fair value based on level 2 inputs [member] | Norwegian kroner (NOK) [Member]
Disclosure of financial liabilities [line items]
Unsecured bonds	380		412
Fair value based on level 2 inputs [member] | Japanese yen (JPY) [Member]
Disclosure of financial liabilities [line items]
Unsecured loans	$ 106		$ 119
Weighted average [member] | United States Dollar (USD) [Member]
Disclosure of financial liabilities [line items]
Weighted average interest rates	3.88%		3.82%
Weighted average [member] | Euro (EUR) [Member]
Disclosure of financial liabilities [line items]
Weighted average interest rates	1.42%		2.03%
Weighted average [member] | Great Britain Pound (GBP) [Member]
Disclosure of financial liabilities [line items]
Weighted average interest rates	6.08%		6.08%
Weighted average [member] | Norwegian kroner (NOK) [Member]
Disclosure of financial liabilities [line items]
Weighted average interest rates	4.18%		4.18%
[1]	1) Restated 1 January 2020 and 31 December and note 21 Provisions and other liabilities.

Finance debt - Bonds (Details)

Finance debt - Bonds (Details) € in Millions, $ in Millions	May 18, 2020EUR (€)	Apr. 01, 2020USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	May 18, 2020USD ($)
Disclosure of financial liabilities [line items]
Bonds			$ 27,568	$ 30,994
Euro (EUR) [Member]
Disclosure of financial liabilities [line items]
Bonds			7,925	10,057
Pure [abstract]
Bonds not swapped			846
United States Dollar (USD) [Member]
Disclosure of financial liabilities [line items]
Bonds			17,451	$ 18,710
Unsecured Bonds [Member] | United States Dollar (USD) [Member]
Disclosure of financial liabilities [line items]
Bonds			17,451
Unsecured Bonds [Member] | All other currencies [Member]
Pure [abstract]
Bonds swapped			9,271
Bonds Maturing January 2026 [Member]
Disclosure of financial liabilities [line items]
Bonds					$ 750
Pure [abstract]
Interest rate in %	1.75%				1.75%
Maturity date	January 2026
Bonds Maturing May 2026 [Member]
Disclosure of financial liabilities [line items]
Bonds | €	€ 750
Pure [abstract]
Interest rate in %	0.75%				0.75%
Maturity date	May 2026
Bonds Maturing May 2030 [Member]
Disclosure of financial liabilities [line items]
Bonds					$ 750
Pure [abstract]
Interest rate in %	2.375%				2.375%
Maturity date	May 2030
Bonds Maturing May 2032 [Member]
Disclosure of financial liabilities [line items]
Bonds | €	€ 1,000
Pure [abstract]
Interest rate in %	1.375%				1.375%
Maturity date	May 2032
Bonds Maturing April 2025 [Member]
Disclosure of financial liabilities [line items]
Bonds		$ 1,250
Pure [abstract]
Interest rate in %		2.875%
Maturity date		April 2025
Bonds Maturing April 2027 [Member]
Disclosure of financial liabilities [line items]
Bonds		$ 500
Pure [abstract]
Interest rate in %		3.00%
Maturity date		April 2027
Bonds Maturing April 2030 [Member]
Disclosure of financial liabilities [line items]
Bonds		$ 1,500
Pure [abstract]
Interest rate in %		3.125%
Maturity date		April 2030
Bonds Maturing April 2040 [Member]
Disclosure of financial liabilities [line items]
Bonds		$ 500
Pure [abstract]
Interest rate in %		3.625%
Maturity date		April 2040
Bonds Maturity April 2050 [Member]
Disclosure of financial liabilities [line items]
Bonds		$ 1,250
Pure [abstract]
Interest rate in %		3.70%
Maturity date		April 2050
Unsecured bonds, 39 Bond agreements [Member]
Disclosure of financial liabilities [line items]
Bonds			$ 27,223

Finance debt - Non-current debt

Finance debt - Non-current debt maturity profile (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Non-current finance debt maturity profile [abstract]
Total repayment of non-current finance debt	$ 27,404	[1]	$ 29,118	[1]	$ 21,754
Weighted average [member]
Non-current finance debt maturity profile [abstract]
Weighted average maturity (years)	10		10
Weighted average [member] | Interest Rate Non Current Debt [Member]
Non-current finance debt maturity profile [abstract]
Weighted average annual interest rate (%)	3.33%		3.38%
Year 2 and 3 [member]
Non-current finance debt maturity profile [abstract]
Total repayment of non-current finance debt	$ 5,015		$ 3,705
Year 4 and 5 [member]
Non-current finance debt maturity profile [abstract]
Total repayment of non-current finance debt	4,731		4,927
After 5 years [member]
Non-current finance debt maturity profile [abstract]
Total repayment of non-current finance debt	$ 17,659		$ 20,485
[1]	1) Restated 1 January 2020 and 31 December and note 21 Provisions and other liabilities.

Finance debt - Current finance

Finance debt - Current finance debt (Details) - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Current finance debt [abstract]
Collateral liabilities	$ 2,271		$ 1,704
Non-current finance debt due within one year	250		1,974
Other including US Commercial paper programme and bank overdraft	2,752		913
Total current finance debt	$ 5,273	[1]	$ 4,591	[1]	$ 2,939
Weighted average interest rate (%)	0.51%		2.40%
Commerical paper program issuance	$ 2,600		$ 903
[1]	1) Restated 1 January 2020 and 31 December and note 21 Provisions and other liabilities.

Finance debt - Reconciliation o

Finance debt - Reconciliation of cash flow from financing activities to finance line items in balance sheet (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of reconciliation of liabilities arising from financing activities [line items]
New finance debt		$ 0	$ 8,347	$ 984
Repayment of finance debt	[1]	(2,675)	(2,055)	(1,314)
Repayment of lease liabilities	[1]	(1,238)	(1,277)	(1,104)
Dividend paid		(1,797)	(2,330)	(3,342)
Share buy-back		(321)	(1,059)	442
Net current finance debt and other financing activities		1,195	1,365	(277)
Cash flows provided by/(used in) financing activities		(4,836)	2,991	(5,496)
Non-current finance debt [member]
Disclosure of reconciliation of liabilities arising from financing activities [line items]
Liabilities arising from financing activities, beginning balance		29,118	21,754
New finance debt			8,347
Repayment of finance debt		(2,675)	(2,055)
Net current finance debt and other financing activities		(335)	72
Cash flows provided by/(used in) financing activities		(3,010)	6,364
Transfer to current portion		1,724	30
Effects of exchange rate changes		(422)	977
Other changes		(6)	(8)
Net other changes		1,296	999
Liabilities arising from financing activities, ending balance		27,404	29,118	21,754
Current finance debt [member]
Disclosure of reconciliation of liabilities arising from financing activities [line items]
Liabilities arising from financing activities, beginning balance		4,591	2,939
Net current finance debt and other financing activities		2,273	1,706
Cash flows provided by/(used in) financing activities		2,273	1,706
Transfer to current portion		(1,724)	(30)
Effects of exchange rate changes		(8)	(27)
Other changes		141	3
Net other changes		(1,591)	(54)
Liabilities arising from financing activities, ending balance		5,273	4,591	2,939
Financial receivable collaterals [Member]
Disclosure of reconciliation of liabilities arising from financing activities [line items]
Liabilities arising from financing activities, beginning balance		(967)	(634)
Net current finance debt and other financing activities		(651)	(329)
Cash flows provided by/(used in) financing activities		(651)	(329)
Effects of exchange rate changes		41
Other changes			(4)
Net other changes		41	(4)
Liabilities arising from financing activities, ending balance		(1,577)	(967)	(634)
Additional paid in capital share based payment/treasury shares [Member]
Disclosure of reconciliation of liabilities arising from financing activities [line items]
Liabilities arising from financing activities, beginning balance		(1,588)	(708)
Share buy-back		(321)	(1,059)
Net current finance debt and other financing activities		(75)	(69)
Cash flows provided by/(used in) financing activities		(396)	(1,128)
Other changes		(43)	248
Net other changes		(43)	248
Liabilities arising from financing activities, ending balance		(2,027)	(1,588)	(708)
Non-controling interest [member]
Disclosure of reconciliation of liabilities arising from financing activities [line items]
Liabilities arising from financing activities, beginning balance		19	20
Net current finance debt and other financing activities		(18)	(16)
Cash flows provided by/(used in) financing activities		(18)	(16)
Effects of exchange rate changes		(1)
Other changes		14	15
Net other changes		13	15
Liabilities arising from financing activities, ending balance		14	19	20
Dividend payable [member]
Disclosure of reconciliation of liabilities arising from financing activities [line items]
Liabilities arising from financing activities, beginning balance		357	859
Dividend paid		(1,797)	(2,330)
Cash flows provided by/(used in) financing activities		(1,797)	(2,330)
Divdend declared		2,041	1,833
Other changes		(19)	(20)
Net other changes		2,022	1,828
Liabilities arising from financing activities, ending balance		582	357	859
Lease liabilities [member]
Disclosure of reconciliation of liabilities arising from financing activities [line items]
Liabilities arising from financing activities, beginning balance		4,406	4,339
Repayment of lease liabilities		(1,238)	(1,277)
Cash flows provided by/(used in) financing activities		(1,238)	(1,277)
Effects of exchange rate changes		(61)	15
New leases		476	1,349
Other changes		(21)	(5)
Net other changes		394	1,344
Liabilities arising from financing activities, ending balance		$ 3,562	4,406	4,339
Lease liabilities [member] | Previously stated [member]
Disclosure of reconciliation of liabilities arising from financing activities [line items]
Liabilities arising from financing activities, beginning balance			$ 4,339
Liabilities arising from financing activities, ending balance				$ 4,339
[1]	Repayment of lease liabilities are separated from the line

Pensions - Net pension cost (De

Pensions - Net pension cost (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)yr	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Disclosure of net defined benefit liability (asset) [abstract]
Description of type of plan	The main pension plans for Equinor ASA and its most significant subsidiaries are defined contribution plans, in which the pension costs are recognised in the Consolidated statement of income in line with payments of annual pension premiums. The pension contribution plans in Equinor ASA also includes certain unfunded elements (notional contribution plans), for which the annual notional contributions are recognised as pension liabilities.
Description of nature of benefits provided by plan	Equinor's defined benefit plans are generally based on a minimum of 30 years of service and 66% of the final salary level, including an assumed benefit from the Norwegian National Insurance Scheme.
Minimum number of years of service for defined benefit plans	P30Y
Defined benefit plan, percentage of final salary level requirement	66.00%
Maximum age of employees for early retirement premium | yr	62
Description of early retirement plan premium calculation	Equinor is a member of a Norwegian national agreement-based early retirement plan (“AFP”), and the premium is calculated based on the employees' income, but limited to 7.1 times the basic amount in the National Insurance scheme (7.1 G).
Duration of Equinor's payment portfolio for earned benefits	P15Y2M12D
Current service cost	$ 209	$ 184	$ 206
Past service cost	3	0	0
Losses (gains) from curtailment, settlement or plan amendment	0	0	3
Notional contributions	60	55	56
Defined benefit plans	272	238	265
Defined contribution plans	213	192	182
Total net pension cost	488	432	$ 446
Interest cost and changes in fair value of notional assets	238	203
Interest income from defined benefit plans	$ 106	$ 117

Pensions - Net pension liabilit

Pensions - Net pension liability (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of net defined benefit liability (asset) [line items]
Current service cost	$ 209	$ 184	$ 206
Past service cost	3	0	0
Losses (gains) from curtailment, settlement or plan amendment	0	0	3
Changes in notional contribution liability	60	55	56
Net pension liability	(2,954)	(2,981)
Represented by
Asset recognised as non-current pension assets (funded plan)	1,449	1,310	1,093
Liability recognised as non-current pension liabilities (unfunded plans)	(4,403)	(4,292)	(3,867)
Actual return on assets	397	501
Funded Plan [Member]
Disclosure of net defined benefit liability (asset) [line items]
Defined benefit obligations, beginning balance	4,927
Defined benefit obligations, ending balance	4,959	4,927
Represented by
DBO specified by funded and unfunded pension plans	4,959	4,927
Unfunded Plan [Member]
Disclosure of net defined benefit liability (asset) [line items]
Defined benefit obligations, beginning balance	4,288
Defined benefit obligations, ending balance	4,400	4,288
Represented by
DBO specified by funded and unfunded pension plans	4,400	4,288
Defined benefit obligations [member]
Disclosure of net defined benefit liability (asset) [line items]
Defined benefit obligations, beginning balance	9,216	8,363
Current service cost	208	184
Interest cost	238	203
Actuarial (gains) losses - Financial assumptions	294	443
Actuarial (gains) losses - Experience	(66)	(61)
Past service cost	3	0
Benefits paid	(295)	(250)
Paid-up policies	0	(7)
Foreign currency translation	(300)	286
Changes in notional contribution liability	60	55
Defined benefit obligations, ending balance	9,358	9,216	8,363
Represented by
DBO specified by funded and unfunded pension plans	9,358	9,216	8,363
Defined benefit plan assets [member]
Disclosure of net defined benefit liability (asset) [line items]
Fair value of plan assets, beginning balance	6,234	5,589
Interest income	106	117
Return on plan assets (excluding interest income)	291	385
Company contributions	114	96
Benefits paid	(137)	(113)
Paid-up policies	0	(7)
Foreign currency translation	(204)	167
Fair value of plan assets, ending balance	$ 6,404	$ 6,234	$ 5,589

Pensions - Actuarial losses and

Pensions - Actuarial losses and gains (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Actuarial losses and gains recognised directly in Other comprehensive income
Net actuarial (losses) gains recognised in OCI during the year	$ 63	$ 3	$ 401
Actuarial (losses) gains related to currency effects on net obligation and foreign exchange translation	84	(109)	27
Tax effects of actuarial (losses) gains recognised in OCI	(35)	19	(98)
Items that will not be reclassified to the Consolidated statement of income	111	(87)	330
Cumulative actuarial (losses) gains recognised directly in OCI net of tax	$ (787)	$ (899)	$ (812)

Pensions - Actuarial assumption

Pensions - Actuarial assumptions (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Weighted-average duration of the defined benefit obligation	15 years 2 months 12 days	15 years 7 months 6 days
Description of Expected attrition	Expected attrition at 31 December 2021 was 0.3% and 3.9% for employees between 50-59 years and 60-67 years, and 0.3% and 3.6% in 2020. The attrition rate for the age group 60-67 years represents employees with immediate withdrawal of vested pension, thus remaining in the scheme.
Employee age group (50-59 years) [Member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Expected attrition rate of employees	0.30%	0.30%
Employee age group (60-67 years) [Member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Expected attrition rate of employees	3.90%	3.60%
Discount rate [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Assumptions used to determine benefit costs	1.75%	2.25%
Percentage Actuarial Assumption To Determine Defined Benefit Obligations	2.00%	1.75%
Rate of compensation increase [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Assumptions used to determine benefit costs	2.00%	2.25%
Percentage Actuarial Assumption To Determine Defined Benefit Obligations	2.50%	2.00%
Expected rate of pension increase [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Assumptions used to determine benefit costs	1.25%	1.50%
Percentage Actuarial Assumption To Determine Defined Benefit Obligations	1.75%	1.25%
Expected increase of social security base amount (G-amount) [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Assumptions used to determine benefit costs	2.00%	2.25%
Percentage Actuarial Assumption To Determine Defined Benefit Obligations	2.25%	2.00%

Pensions - Sensitivity analysis

Pensions - Sensitivity analysis (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)yr
Discount rate [member] | Low range value [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Defined benefit obligation, change due to decrease in assumption	$ 731
Service cost 2020, decrease	$ 24
Percentage of reasonably possible decrease in actuarial assumption	(0.50%)
Discount rate [member] | High range value [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Defined benefit obligation, change due to increase in assumption	$ (645)
Service cost 2020, increase	$ (20)
Percentage of reasonably possible increase in actuarial assumption	0.50%
Expected rate of compensation [member] | Low range value [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Defined benefit obligation, change due to decrease in assumption	$ (150)
Service cost 2020, decrease	$ (9)
Percentage of reasonably possible decrease in actuarial assumption	(0.50%)
Expected rate of compensation [member] | High range value [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Defined benefit obligation, change due to increase in assumption	$ 157
Service cost 2020, increase	$ 10
Percentage of reasonably possible increase in actuarial assumption	0.50%
Expected rate of pension increase [member] | Low range value [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Defined benefit obligation, change due to decrease in assumption	$ (545)
Service cost 2020, decrease	$ (14)
Percentage of reasonably possible decrease in actuarial assumption	(0.50%)
Expected rate of pension increase [member] | High range value [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Defined benefit obligation, change due to increase in assumption	$ 601
Service cost 2020, increase	$ 16
Percentage of reasonably possible increase in actuarial assumption	0.50%
Mortality assumption [member] | Low range value [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Defined benefit obligation, change due to decrease in assumption	$ (330)
Service cost 2020, decrease	$ (7)
Increase (decrease) in mortality age assumption | yr	(1)
Mortality assumption [member] | High range value [member]
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Defined benefit obligation, change due to increase in assumption	$ 367
Service cost 2020, increase	$ 8
Increase (decrease) in mortality age assumption | yr	1

Pensions - assets, portfolio we

Pensions - assets, portfolio weighting (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Disclosure of financial assets [line items]
Pension assets on investment classes, percentage	100.00%	100.00%
Low range value [member]
Disclosure of financial assets [line items]
Company contributions	$ 100
High range value [member]
Disclosure of financial assets [line items]
Company contributions	$ 110
Equity securities [member]
Disclosure of financial assets [line items]
Pension assets on investment classes, percentage	34.10%	34.10%
Equity securities [member] | Low range value [member]
Disclosure of financial assets [line items]
Target porfolio weight	29.00%
Equity securities [member] | High range value [member]
Disclosure of financial assets [line items]
Target porfolio weight	38.00%
Equity securities [member] | Level 1 [member]
Disclosure of financial assets [line items]
Percentange of pension assets measured at fair value	61.00%	81.00%
Equity securities [member] | Level 2 [member]
Disclosure of financial assets [line items]
Percentange of pension assets measured at fair value	37.00%	17.00%
Bonds [Member]
Disclosure of financial assets [line items]
Pension assets on investment classes, percentage	50.20%	50.20%
Bonds [Member] | Low range value [member]
Disclosure of financial assets [line items]
Target porfolio weight	46.00%
Bonds [Member] | High range value [member]
Disclosure of financial assets [line items]
Target porfolio weight	59.00%
Bonds [Member] | Level 1 [member]
Disclosure of financial assets [line items]
Percentange of pension assets measured at fair value	3.00%	2.00%
Bonds [Member] | Level 2 [member]
Disclosure of financial assets [line items]
Percentange of pension assets measured at fair value	97.00%	98.00%
Money market instruments [Member]
Disclosure of financial assets [line items]
Pension assets on investment classes, percentage	9.10%	9.40%
Money market instruments [Member] | Low range value [member]
Disclosure of financial assets [line items]
Target porfolio weight	0.00%
Money market instruments [Member] | High range value [member]
Disclosure of financial assets [line items]
Target porfolio weight	14.00%
Money market instruments [Member] | Level 2 [member]
Disclosure of financial assets [line items]
Percentange of pension assets measured at fair value	100.00%	100.00%
Real estate [Member]
Disclosure of financial assets [line items]
Pension assets on investment classes, percentage	6.60%	6.40%
Real estate [Member] | Low range value [member]
Disclosure of financial assets [line items]
Target porfolio weight	5.00%
Real estate [Member] | High range value [member]
Disclosure of financial assets [line items]
Target porfolio weight	10.00%
Other assets [Member]
Disclosure of financial assets [line items]
Pension assets on investment classes, percentage	0.00%	(0.10%)

Provisions and other liabilit_3

Provisions and other liabilities (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	$ 22,568	[1]
Current portion, reported as trade, other payables and provisions, beginning	2,649
Provisions and other liabilities at the beginning period	25,216
New or increased provisions and other liabilities	984
Change in estimates	(1,296)
Amounts charged against provisions and other liabilities	(1,519)
Effects of change in the discount rate	(1,623)
Reduction due to divestments	(359)
Accretion expenses	452
Reclassification and transfer	224
Currency translation	(476)
Provisions and other liabilities at ending period	21,603
Non-current portion - ending period	19,899	[1]
Current portion, reported as trade, other payables and provisions, ending	1,704
Before restatement [member]
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	19,731
Impact of ARO policy change [member]
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	2,837
Non-current portion - ending period	1,751
Asset retirement obligations [Member]
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	20,037
Current portion, reported as trade, other payables and provisions, beginning	92
Provisions and other liabilities at the beginning period	20,128
New or increased provisions and other liabilities	602
Change in estimates	(1,097)
Amounts charged against provisions and other liabilities	(125)
Effects of change in the discount rate	(1,610)
Reduction due to divestments	(359)
Accretion expenses	423
Reclassification and transfer	(74)
Currency translation	(471)
Provisions and other liabilities at ending period	17,417
Non-current portion - ending period	17,279
Current portion, reported as trade, other payables and provisions, ending	138
Asset retirement obligations [Member] | Before restatement [member]
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	17,200
Asset retirement obligations [Member] | Impact of ARO policy change [member]
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	2,837
Claims and litigations [Member]
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	96
Current portion, reported as trade, other payables and provisions, beginning	958
Provisions and other liabilities at the beginning period	1,053
New or increased provisions and other liabilities	30
Change in estimates	(58)
Amounts charged against provisions and other liabilities	(870)
Reclassification and transfer	0
Currency translation	0
Provisions and other liabilities at ending period	155
Non-current portion - ending period	81
Current portion, reported as trade, other payables and provisions, ending	73
Claims and litigations [Member] | Before restatement [member]
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	96
Claims and litigations [Member] | Impact of ARO policy change [member]
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	0
Other provisions [Member]
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	2,436
Current portion, reported as trade, other payables and provisions, beginning	1,600
Provisions and other liabilities at the beginning period	4,035
New or increased provisions and other liabilities	352
Change in estimates	(141)
Amounts charged against provisions and other liabilities	(524)
Effects of change in the discount rate	(13)
Accretion expenses	29
Reclassification and transfer	298
Currency translation	(5)
Provisions and other liabilities at ending period	4,031
Non-current portion - ending period	2,539
Current portion, reported as trade, other payables and provisions, ending	1,493
Other provisions [Member] | Before restatement [member]
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	2,436
Other provisions [Member] | Impact of ARO policy change [member]
Disclosure of other provisions and other liabilities [line items]
Non-current portion - beginning period	$ 0
[1]	1) Restated 1 January 2020 and 31 December and note 21 Provisions and other liabilities.

Provisions and other liabilit_4

Provisions and other liabilities - Restatement of ARO due to change in the discount rate (Details) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of other provisions and other liabilities [line items]
PPE		$ 62,075	$ 68,508	$ 71,751
Total non-current assets		84,618	92,623	95,083
Total assets		147,120	124,809	119,861
Provisions and other liabilities	[1]	19,899	22,568	19,750
Total non-current liabilities		68,959	71,097	59,144
Total liabilities		108,096	90,917	78,702
Before restatement [member]
Disclosure of other provisions and other liabilities [line items]
PPE			65,672	69,953
Total non-current assets			89,786	93,285
Total assets			121,972	118,063
Provisions and other liabilities			19,731	17,951
Total non-current liabilities			68,260	57,346
Total liabilities			88,081	76,904
Impact of ARO policy change [member]
Disclosure of other provisions and other liabilities [line items]
PPE		1,751	2,836	1,798
Total non-current assets			2,836	1,798
Total assets			2,836	1,798
Provisions and other liabilities		$ 1,751	2,837	1,798
Total non-current liabilities			2,837	1,798
Total liabilities			$ 2,837	$ 1,798
[1]	1) Restated 1 January 2020 and 31 December and note 21 Provisions and other liabilities.

Provisions and other liabilit_5

Provisions and other liabilities - Expected timing of cash outflows (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Disclosure of other provisions and other liabilities [line items]
Total provision	$ 21,603	$ 25,216
2022 - 2026 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	4,194
2027 - 2031 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	1,896
2032 - 2036 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	4,563
2037 - 2041 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	6,207
Thereafter [Member]
Disclosure of other provisions and other liabilities [line items]
Total provision	4,742
Asset retirement obligations [Member]
Disclosure of other provisions and other liabilities [line items]
Total provision	17,417	20,128
Asset retirement obligations [Member] | 2022 - 2026 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	1,180
Asset retirement obligations [Member] | 2027 - 2031 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	1,597
Asset retirement obligations [Member] | 2032 - 2036 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	4,315
Asset retirement obligations [Member] | 2037 - 2041 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	6,152
Asset retirement obligations [Member] | Thereafter [Member]
Disclosure of other provisions and other liabilities [line items]
Total provision	4,173
Other provisions, including claims and litigations [Member]
Disclosure of other provisions and other liabilities [line items]
Total provision	4,186
Other provisions, including claims and litigations [Member] | 2022 - 2026 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	3,014
Other provisions, including claims and litigations [Member] | 2027 - 2031 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	299
Other provisions, including claims and litigations [Member] | 2032 - 2036 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	248
Other provisions, including claims and litigations [Member] | 2037 - 2041 [member]
Disclosure of other provisions and other liabilities [line items]
Total provision	55
Other provisions, including claims and litigations [Member] | Thereafter [Member]
Disclosure of other provisions and other liabilities [line items]
Total provision	$ 569
Onerous contracts, cancellation fees and other [Member]
Disclosure of other provisions and other liabilities [line items]
Total provision		$ 166

Trade, other payables and pro_3

Trade, other payables and provisions (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of transactions between related parties [line items]
Trade payables	$ 6,249	$ 2,748
Non-trade payables and accrued expenses	2,181	2,352
Total financial trade and other payables	12,351	7,736
Current portion of provisions and other non-financial payables	1,960	2,774
Trade, other payables and provisions	14,310	10,510	$ 10,450
Joint venture [member]
Disclosure of transactions between related parties [line items]
Related party payables	1,876	2,090
Equity accounted associated companies and other related parties
Disclosure of transactions between related parties [line items]
Related party payables	$ 2,045	$ 546

Leases - Information related to

Leases - Information related to lease payments and lease liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Lease liabilities [abstract]
Lease interest	$ 93		$ 104		$ 126
Current leases, presented within current Finance debt	1,113	[1]	1,186	[1]	1,148
Noncurrent Leases	2,449	[1]	3,220	[1]	3,191
Lease liabilities [member]
Lease liabilities [abstract]
Liabilities arising from financing activities, beginning balance	4,406		4,339
New leases, Including remeasurements and cancelations	476		1,349
Gross lease payments	(1,350)		(1,415)
Lease interest	91		102
Lease repayments	(1,259)		(1,313)
Foreign currency translation effects	(61)		31
Liabilities arising from financing activities, ending balance	$ 3,562		$ 4,406		$ 4,339
[1]	1) Restated 1 January 2020 and 31 December and note 21 Provisions and other liabilities.

Leases - Lease payments not inc

Leases - Lease payments not included in lease liability (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Disclosure of quantitative information about leases for lessee [abstract]
Short term lease expense	$ 160	$ 342
Lease revenue	272	252
Repayments received related to finance subleases	4	29
Total finance sublease receivables	$ 104	$ 38

Leases - Non-current debt matur

Leases - Non-current debt maturity profile (Details) - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Lease liabilities [abstract]
Total repayment of non-current lease liability	$ 2,449	[1]	$ 3,220	[1]	$ 3,191
Year 2 and 3 [member]
Lease liabilities [abstract]
Total repayment of non-current lease liability	1,164		1,513
Year 4 and 5 [member]
Lease liabilities [abstract]
Total repayment of non-current lease liability	586		748
After 5 years [member]
Lease liabilities [abstract]
Total repayment of non-current lease liability	$ 699		$ 959
[1]	1) Restated 1 January 2020 and 31 December and note 21 Provisions and other liabilities.

Leases - Information related _2

Leases - Information related to Right of use assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Disclosure of quantitative information about right-of-use assets [line items]
Right of use Assets	$ 4,119	$ 4,011
Additions including remeasurements and cancellations	427	1,326
Depreciation and impairment	(1,265)	(1,257)
Currency and other	(50)	40
Right of use Assets	3,231	4,119
Drilling Rigs [Member]
Disclosure of quantitative information about right-of-use assets [line items]
Right of use Assets	1,004	951
Additions including remeasurements and cancellations	14	380
Depreciation and impairment	(316)	(349)
Currency and other	(26)	23
Right of use Assets	675	1,004
Vessels [Member]
Disclosure of quantitative information about right-of-use assets [line items]
Right of use Assets	1,606	1,320
Additions including remeasurements and cancellations	300	853
Depreciation and impairment	(617)	(571)
Currency and other	(8)	4
Right of use Assets	1,280	1,606
Land and buildings [member]
Disclosure of quantitative information about right-of-use assets [line items]
Right of use Assets	1,215	1,365
Additions including remeasurements and cancellations	28	18
Depreciation and impairment	(176)	(179)
Currency and other	(12)	11
Right of use Assets	1,055	1,215
Storage facilities [Member]
Disclosure of quantitative information about right-of-use assets [line items]
Right of use Assets	133	156
Additions including remeasurements and cancellations	8	45
Depreciation and impairment	(72)	(68)
Currency and other	0	0
Right of use Assets	68	133
Other [Member]
Disclosure of quantitative information about right-of-use assets [line items]
Right of use Assets	161	219
Additions including remeasurements and cancellations	78	30
Depreciation and impairment	(82)	(90)
Currency and other	(5)	2
Right of use Assets	152	161
Assets under development [Member]
Disclosure of quantitative information about right-of-use assets [line items]
Depreciation and impairment	$ (320)	$ (359)

Other commitments, contingent_3

Other commitments, contingent liabilities and contingent assets (Details) $ in Millions	1 Months Ended	12 Months Ended
	Jun. 30, 2021USD ($)	Dec. 31, 2021USD ($)Wells	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Disclosure of other provisions and other liabilities [line items]
Contractual commitments		$ 7,038
Trade, other payables and provisions		14,310	$ 10,510	$ 10,450
Wells committed to drill [member]
Disclosure of other provisions and other liabilities [line items]
Contractual commitments		$ 409
Number of wells, committed to drill | Wells		36
Average ownership interest in wells committed to drill		46.00%
Various long term agreements [Member] | Maximum [member]
Disclosure of other provisions and other liabilities [line items]
Contract Term		2060
Leases Agreements [Member]
Disclosure of other provisions and other liabilities [line items]
Provisions, net of tax		$ 2,022
Agbami redetermination [member]
Disclosure of other provisions and other liabilities [line items]
Reduction in exposure	$ 822
Other Revenue	$ 57
Guarantees [member]
Disclosure of other provisions and other liabilities [line items]
Estimated exposure		439
Claim from Petrofac [member]
Disclosure of other provisions and other liabilities [line items]
Estimated exposure		$ 163
Percentage Share of Contingent Liability		31.85%
Claim from Petrofac [member] | Petrofac International (UAE) LLC [Member]
Disclosure of other provisions and other liabilities [line items]
Estimated exposure		$ 533
Dispute with Brazilian tax authorities [member] | Maximum [member]
Disclosure of other provisions and other liabilities [line items]
Estimated exposure		135
ICMS indirect tax [member]
Disclosure of other provisions and other liabilities [line items]
Estimated exposure		$ 460
Indirect tax rate		18.00%
KKD oil sands partnership [Member]
Disclosure of other provisions and other liabilities [line items]
Proportion of ownership interest divested		40.00%
KKD oil sands partnership [Member] | Maximum [member]
Disclosure of other provisions and other liabilities [line items]
Estimated exposure		$ 397
Norwegian tax authorities [member] | Maximum [member]
Disclosure of other provisions and other liabilities [line items]
Estimated exposure		182
Research & Development cost [Member] | Maximum [member]
Disclosure of other provisions and other liabilities [line items]
Estimated exposure		206
Internal pricing of certain products of natural gas liquids [Member] | Maximum [member]
Disclosure of other provisions and other liabilities [line items]
Estimated exposure		$ 100
New Brazilian law [Member]
Disclosure of other provisions and other liabilities [line items]
Percent of savings from ICMS tax incentives		10.00%
New Brazilian law [Member] | Maximum [member]
Disclosure of other provisions and other liabilities [line items]
Estimated exposure		$ 112

Other commitments, contingent_4

Other commitments, contingent liabilities and contingent assets - long-term commitments (Details) $ in Millions	Dec. 31, 2021USD ($)
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Contractual and other long term commitments	$ 13,140
2022 [member]
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Contractual and other long term commitments	2,663
2023 [member]
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Contractual and other long term commitments	2,077
2024 [member]
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Contractual and other long term commitments	1,520
2025 [member]
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Contractual and other long term commitments	1,307
2026 [member]
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Contractual and other long term commitments	1,026
Thereafter [member]
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Contractual and other long term commitments	$ 4,547

Related parties - narrative (De

Related parties - narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jul. 31, 2021
Disclosure of transactions between related parties [line items]
Amounts payable, related party transactions	$ 0	$ 0	$ 0
Share buyback programme [member] | Share-based Payment Arrangement, Tranche One [member]
Disclosure of transactions between related parties [line items]
Agreement to buy treasury shares	$ 600,000,000			$ 300,000,000
Equinor ASA [member]
Disclosure of transactions between related parties [line items]
Ownership interests held by shareholder	67.00%
Equinor ASA [member] | Lease liabilities [member]
Disclosure of transactions between related parties [line items]
Amounts payable, related party transactions	$ 284,000,000
Related Party Lease Contract Term	The lease contracts extend to the years 2034 and 2037
Equinor ASA [member] | Gassco AS [member]
Disclosure of transactions between related parties [line items]
Settlement of liabilities by entity on behalf of related party, related party transactions	$ 1,030,000,000	896,000,000	1,076,000,000
Norwegian State [member]
Disclosure of transactions between related parties [line items]
Amounts receivable, related party transactions	435,000,000	169,000,000
Norwegian State [member] | Oil and gas assets [member]
Disclosure of transactions between related parties [line items]
Purchases of of goods with related party	9,572,000,000	5,108,000,000	7,505,000,000
Norwegian State [member] | Tjeldbergodden [member]
Disclosure of transactions between related parties [line items]
Purchases of of goods with related party	$ 88,000,000	$ 18,000,000	$ 36,000,000
Folketrygdfondet [member]
Disclosure of transactions between related parties [line items]
Ownership interests held by shareholder	3.70%

Financial instruments - Classes

Financial instruments - Classes of financial assets instruments (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Asset [abstract]
Noncurrent Derivative Financial Assets	$ 1,265	$ 2,476	$ 1,365
Non-current financial investments	3,346	4,083	3,600
Prepayments and financial receivables	1,087	861	1,214
Trade and other receivables	17,927	8,232	8,233
Current Derivative Financial Assets	5,131	886	578
Current financial investments	21,246	11,865
Cash and cash equivalents	14,126	6,757	$ 5,177
Total	64,128	35,159
Classification correction [Member]
Asset [abstract]
Prepayments and financial receivables		32
Non-financial assets [member]
Asset [abstract]
Prepayments and financial receivables	380	396
Trade and other receivables	736	814
Total	1,116	1,210
Amortised cost [member]
Asset [abstract]
Non-current financial investments	253	261
Prepayments and financial receivables	707	465
Trade and other receivables	17,192	7,418
Current financial investments	20,946	11,649
Cash and cash equivalents	11,412	6,264
Total	50,510	26,057
Financial assets at fair value through profit or loss, category [member]
Asset [abstract]
Noncurrent Derivative Financial Assets	1,265	2,476
Non-current financial investments	3,093	3,822
Current Derivative Financial Assets	5,131	886
Current financial investments	300	216
Cash and cash equivalents	2,714	492
Total	$ 12,503	$ 7,892

Financial instruments - Class_2

Financial instruments - Classes of financial liabilities instruments (Details) - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Liabilities [abstract]
Non-current finance debt	$ 27,404	[1]	$ 29,118	[1]	$ 21,754
Non-current derivative financial instruments	767		676
Trade and other payables	14,310		10,510		10,450
Current finance debt	5,273	[1]	4,591	[1]	2,939
Dividend payable	582		357		859
Current Derivative Financial Liabilities	4,609		1,710		$ 462
Total	52,945		46,961
Non-financial liabilities [member]
Liabilities [abstract]
Trade and other payables	1,960		2,774
Total	1,960		2,774
Amortised cost [member]
Liabilities [abstract]
Non-current finance debt	27,404		29,118
Trade and other payables	12,350		7,736
Current finance debt	5,273		4,591
Dividend payable	582		357
Total	45,609		41,802
Financial liabilities at fair value through profit or loss, category [member]
Liabilities [abstract]
Non-current derivative financial instruments	767		676
Current Derivative Financial Liabilities	4,609		1,710
Total	$ 5,376		$ 2,386
[1]	1) Restated 1 January 2020 and 31 December and note 21 Provisions and other liabilities.

Financial instruments - Fair va

Financial instruments - Fair value heirarchy (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disclosure of fair value measurement [line items]
Non-current derivative financial instruments - assets	$ 1,265	$ 2,476	$ 1,365
Current financial investments	21,246	11,865
Current derivative financial instruments - assets	5,131	886	578
Non-current derivative financial instruments - liabilities	(767)	(676)
Current derivative financial instruments liabilities	(4,609)	(1,710)	$ (462)
Fair value [member]
Disclosure of fair value measurement [line items]
Non-current financial investments	3,093	3,822
Non-current derivative financial instruments - assets	1,265	2,476
Current financial investments	300	216
Current derivative financial instruments - assets	5,131	886
Cash equivalents	2,714	492
Non-current derivative financial instruments - liabilities	(767)	(676)
Current derivative financial instruments liabilities	(4,609)	(1,710)
Net fair value	7,127	5,505
Level 1 [member]
Disclosure of fair value measurement [line items]
Non-current financial investments	860	1,379
Non-current derivative financial instruments - assets	0	0
Current financial investments	0	66
Current derivative financial instruments - assets	949	419
Non-current derivative financial instruments - liabilities	0	0
Current derivative financial instruments liabilities	(69)	(432)
Net fair value	1,740	1,432
Level 2 [member]
Disclosure of fair value measurement [line items]
Non-current financial investments	1,840	2,135
Non-current derivative financial instruments - assets	884	2,146
Current financial investments	300	150
Current derivative financial instruments - assets	4,108	443
Cash equivalents	2,714	492
Non-current derivative financial instruments - liabilities	(762)	(671)
Current derivative financial instruments liabilities	(4,539)	(1,277)
Net fair value	4,545	3,418
Level 3 [member]
Disclosure of fair value measurement [line items]
Non-current financial investments	393	308
Non-current derivative financial instruments - assets	380	330
Current derivative financial instruments - assets	74	24
Non-current derivative financial instruments - liabilities	(4)	(5)
Net fair value	$ 843	$ 657

Financial instruments - Reconci

Financial instruments - Reconciliation of changes in fair value (Details) - Level 3 [member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Disclosure of fair value measurement [line items]
Opening balance	$ 657	$ 510
Total gains and losses recognised in statement of income, assets	108	109
Purchases, assets	119	64
Settlement, assets	(27)	(36)
Transfer to level 1	0	1
Foreign currency translation differences	(13)	9
Closing balance	844	657
Non-current derivative financial instruments liabilities [Member]
Disclosure of fair value measurement [line items]
Opening balance	(5)	(19)
Total gains and losses recognised in statement of income, liabilities	1	14
Closing balance	(4)	(5)
Non-current financial investments [Member]
Disclosure of fair value measurement [line items]
Opening balance	308	277
Total gains and losses recognised in statement of income, assets	(23)	(29)
Purchases, assets	119	64
Settlement, assets	(7)	(8)
Transfer to level 1	0	1
Foreign currency translation differences	(3)	4
Closing balance	394	308
Non-current derivative financial instruments - assets [Member]
Disclosure of fair value measurement [line items]
Opening balance	330	219
Total gains and losses recognised in statement of income, assets	58	106
Foreign currency translation differences	(8)	5
Closing balance	380	330
Current derivative financial instruments, assets [Member]
Disclosure of fair value measurement [line items]
Opening balance	24	33
Total gains and losses recognised in statement of income, assets	72	19
Settlement, assets	(20)	(28)
Foreign currency translation differences	(2)	0
Closing balance	$ 74	$ 24

Financial instruments - Sensiti

Financial instruments - Sensitivity analysis of market risk (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Price Assumptions Used For Impairment Calculations [Line Items]
Gains (losses) derivative financial instruments	$ (708)	$ 448	$ 473
Commodity price sensitivity [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Percentage of reasonably possible change, market risk	30.00%
Commodity price sensitivity [member] | Minimum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Percentage of reasonably possible change, market risk	(0.30%)	(0.30%)
Commodity price sensitivity [member] | Maximum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Percentage of reasonably possible change, market risk	0.30%	0.30%
Commodity price sensitivity [member] | Crude oil and refined products [member] | Minimum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Gains (losses) derivative financial instruments	$ 735	$ 1,025
Commodity price sensitivity [member] | Crude oil and refined products [member] | Maximum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Gains (losses) derivative financial instruments	(735)	(1,025)
Commodity price sensitivity [member] | Natural gas and electricity [Member] | Minimum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Gains (losses) derivative financial instruments	227	184
Commodity price sensitivity [member] | Natural gas and electricity [Member] | Maximum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Gains (losses) derivative financial instruments	$ (141)	$ (94)
Equity price risk [member] | Minimum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Percentage of reasonably possible change, market risk	(35.00%)	(35.00%)
Net gains (losses)	$ (534)	$ (684)
Equity price risk [member] | Maximum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Percentage of reasonably possible change, market risk	35.00%	35.00%
Net gains (losses)	$ 534	$ 684
Currency risk sensitivity [member] | Minimum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Percentage of reasonably possible change, market risk	(10.00%)	(8.00%)
Currency risk sensitivity [member] | Minimum (%) [member] | United States Dollar (USD) [Member]
Price Assumptions Used For Impairment Calculations [Line Items]
Foreign exchange gain (loss)	$ (1,789)	$ (319)
Currency risk sensitivity [member] | Minimum (%) [member] | Norwegian kroner (NOK) [Member]
Price Assumptions Used For Impairment Calculations [Line Items]
Foreign exchange gain (loss)	$ 2,144	$ 322
Currency risk sensitivity [member] | Maximum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Percentage of reasonably possible change, market risk	10.00%	8.00%
Currency risk sensitivity [member] | Maximum (%) [member] | United States Dollar (USD) [Member]
Price Assumptions Used For Impairment Calculations [Line Items]
Foreign exchange gain (loss)	$ 1,789	$ 319
Currency risk sensitivity [member] | Maximum (%) [member] | Norwegian kroner (NOK) [Member]
Price Assumptions Used For Impairment Calculations [Line Items]
Foreign exchange gain (loss)	$ (2,144)	$ (322)
Interest rate sensitivity [member] | Minimum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Percentage of reasonably possible change, market risk	0.80%	0.60%
Net gains (losses)	$ 448	$ 516
Interest rate sensitivity [member] | Maximum (%) [member]
Price Assumptions Used For Impairment Calculations [Line Items]
Percentage of reasonably possible change, market risk	(0.80%)	(0.60%)
Net gains (losses)	$ (448)	$ (516)

Financial instruments - Narrati

Financial instruments - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Commodity price sensitivity [member]
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of reasonably possible change, market risk	30.00%
Level 3 [member]
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Total gains and losses recognised in statement of income, assets	$ 108	$ 109
Gains on change in fair value of derivatives	86
The amount of increase (decrease) in the fair value of asset	187
Level 3 [member] | Market Risk [member]
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Total gains and losses recognised in statement of income, assets	20
Level 3 [member] | Certain earn-out agreements [member]
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Total gains and losses recognised in statement of income, assets	108
Extrapolation approach [member] | Level 3 [member] | Certain earn-out agreements [member]
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
The amount of increase (decrease) in the fair value of asset	$ 400	$ 100

Subsequent event (Details)

Subsequent event (Details) MMBoe in Millions, $ in Millions	Feb. 28, 2022USD ($)MMBoe	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)
Disclosure of non-adjusting events after reporting period [line items]
Non-current assets		$ 71,213	$ 78,919
Russia [member]
Disclosure of non-adjusting events after reporting period [line items]
Non-current assets		$ 1,235	$ 973
Process of exiting Equinor's joint arrangements [member] | Russia [member] | E&P International [member]
Disclosure of non-adjusting events after reporting period [line items]
Non-current assets	$ 1,200
Oil and gas reserves | MMBoe	88