Pacific Gas & Electric (PCG+A) 10-K10 Feb 222021 FY Annual reportFinancial data

Company Profile

Cover Page

Cover Page - USD ($) $ in Millions	12 Months Ended
Cover Page - USD ($) $ in Millions	Dec. 31, 2021	Feb. 04, 2022	Jun. 30, 2021
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2021
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	1-12609
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	94-3234914
Entity Address, Address Line One	77 Beale Street
Entity Address, Address Line Two	P.O. Box 770000
Entity Address, City or Town	San Francisco,
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	94117
City Area Code	415
Local Phone Number	973-1000
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Bankruptcy Proceedings, Reporting Current	true
Entity Public Float			$ 20,185
Entity Common Stock, Shares Outstanding (in shares)		2,463,891,104
Documents Incorporated by Reference	DOCUMENTS INCORPORATED BY REFERENCE Portions of the documents listed below have been incorporated by reference into the indicated parts of this report, as specified in the responses to the item numbers involved: Designated portions of the Joint Proxy Statement relating to the 2021 Annual Meetings of Shareholders Part III (Items 10, 11, 12, 13 and 14)
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
Entity Registrant Name	PG&E CORP
Entity Central Index Key	0001004980
Auditor Name	DELOITTE & TOUCHE LLP
Auditor Firm ID	34
Auditor Location	San Francisco, California
Pacific Gas & Electric Co (Utility)
Document Type	10-K
Entity File Number	1-2348
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	94-0742640
Entity Address, Address Line One	77 Beale Street
Entity Address, Address Line Two	P.O. Box 770000
Entity Address, City or Town	San Francisco,
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	94117
City Area Code	415
Local Phone Number	973-1000
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Bankruptcy Proceedings, Reporting Current	true
Entity Common Stock, Shares Outstanding (in shares)		264,374,809
Documents Incorporated by Reference	DOCUMENTS INCORPORATED BY REFERENCE Portions of the documents listed below have been incorporated by reference into the indicated parts of this report, as specified in the responses to the item numbers involved: Designated portions of the Joint Proxy Statement relating to the 2021 Annual Meetings of Shareholders Part III (Items 10, 11, 12, 13 and 14)
Entity Registrant Name	PACIFIC GAS & ELECTRIC CO
Entity Central Index Key	0000075488
The New York Stock Exchange \| Common stock, no par value
Title of 12(b) Security	Common stock, no par value
Trading Symbol	PCG
Security Exchange Name	NYSE
The New York Stock Exchange \| Equity Units
Title of 12(b) Security	Equity Units
Trading Symbol	PCGU
Security Exchange Name	NYSE
NYSE American LLC \| First preferred stock, cumulative, par value $25 per share, 5% series A redeemable
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 5% series A redeemable
Trading Symbol	PCG-PE
Security Exchange Name	NYSEAMER
NYSE American LLC \| First preferred stock, cumulative, par value $25 per share, 5% redeemable
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 5% redeemable
Trading Symbol	PCG-PD
Security Exchange Name	NYSEAMER
NYSE American LLC \| First preferred stock, cumulative, par value $25 per share, 4.80% redeemable
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 4.80% redeemable
Trading Symbol	PCG-PG
Security Exchange Name	NYSEAMER
NYSE American LLC \| First preferred stock, cumulative, par value $25 per share, 4.50% redeemable
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 4.50% redeemable
Trading Symbol	PCG-PH
Security Exchange Name	NYSEAMER
NYSE American LLC \| First preferred stock, cumulative, par value $25 per share, 4.36% series A redeemable
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 4.36% series A redeemable
Trading Symbol	PCG-PI
Security Exchange Name	NYSEAMER
NYSE American LLC \| First preferred stock, cumulative, par value $25 per share, 6% nonredeemable
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 6% nonredeemable
Trading Symbol	PCG-PA
Security Exchange Name	NYSEAMER
NYSE American LLC \| First preferred stock, cumulative, par value $25 per share, 5.50% nonredeemable
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 5.50% nonredeemable
Trading Symbol	PCG-PB
Security Exchange Name	NYSEAMER
NYSE American LLC \| First preferred stock, cumulative, par value $25 per share, 5% nonredeemable
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 5% nonredeemable
Trading Symbol	PCG-PC
Security Exchange Name	NYSEAMER

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Revenues
Total operating revenues	$ 20,642	$ 18,469	$ 17,129
Operating Expenses
Operating and maintenance	10,200	8,684	8,725
Wildfire-related claims, net of recoveries	258	251	11,435
Wildfire fund expense	517	413	0
Depreciation, amortization, and decommissioning	3,403	3,468	3,234
Total operating expenses	18,759	16,714	27,223
Operating Income (Loss)	1,883	1,755	(10,094)
Interest income	20	39	82
Interest expense	(1,601)	(1,260)	(934)
Other income, net	457	483	250
Reorganization items, net	(11)	(1,959)	(346)
Income (Loss) Before Income Taxes	748	(942)	(11,042)
Income tax provision (benefit)	836	362	(3,400)
Net Loss	(88)	(1,304)	(7,642)
Preferred stock dividend requirement of subsidiary	14	14	14
Loss Attributable to Common Shareholders	$ (102)	$ (1,318)	$ (7,656)
Weighted Average Common Shares Outstanding, Basic (in shares)	1,985	1,257	528
Weighted Average Common Shares Outstanding, Diluted (in shares)	1,985	1,257	528
Net Loss Per Common Share, Basic (in dollars per share)	$ (0.05)	$ (1.05)	$ (14.50)
Net Loss Per Common Share, Diluted (in dollars per share)	$ (0.05)	$ (1.05)	$ (14.50)
Electric
Operating Revenues
Total operating revenues	$ 15,131	$ 13,858	$ 12,740
Operating Expenses
Cost of electricity and natural gas	3,232	3,116	3,095
Natural gas
Operating Revenues
Total operating revenues	5,511	4,611	4,389
Operating Expenses
Cost of electricity and natural gas	$ 1,149	$ 782	$ 734

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Comprehensive Income [Abstract]
Net Loss	$ (88)	$ (1,304)	$ (7,642)
Other Comprehensive Income (Loss)
Pension and other postretirement benefit plans obligations (net of taxes of $3, $7, and $0, at respective dates)	7	(17)	(1)
Total other comprehensive income (loss)	7	(17)	(1)
Comprehensive Loss	(81)	(1,321)	(7,643)
Preferred stock dividend requirement of subsidiary	14	14	14
Comprehensive Loss Attributable to Common Shareholders	$ (95)	$ (1,335)	$ (7,657)

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Comprehensive Income [Abstract]
Pension and other postretirement benefit plans obligations, tax	$ 3	$ 7	$ 0

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Current Assets
Cash and cash equivalents	$ 291	$ 484
Restricted Cash	16	143
Accounts receivable
Customers (net of allowance for doubtful accounts of $171 million and $146 million at respective dates) (includes $2.06 billion and $1.63 billion related to VIEs, net of allowance for doubtful accounts of $171 million and $143 million at respective dates)	2,345	1,883
Accrued unbilled revenue (includes $1.09 billion and $959 million related to VIEs at respective dates)	1,207	1,083
Regulatory balancing accounts	2,999	2,001
Other	1,784	1,172
Regulatory assets	496	410
Inventories
Gas stored underground and fuel oil	44	95
Materials and supplies	552	533
Wildfire fund asset	461	464
Other	882	1,334
Total current assets	11,077	9,602
Property, Plant, and Equipment
Electric	69,482	66,982
Gas	25,979	24,135
Construction work in progress	3,479	2,757
Financing lease and other	20	20
Total property, plant, and equipment	98,960	93,894
Accumulated depreciation	(29,134)	(27,758)
Net property, plant, and equipment	69,826	66,136
Other Noncurrent Assets
Regulatory assets	9,207	8,978
Nuclear decommissioning trusts	3,798	3,538
Operating lease right of use asset	1,234	1,741
Wildfire fund asset	5,313	5,816
Income taxes receivable	9	67
Other (includes net noncurrent accounts receivable of $187 million and $0 related to VIEs, net of noncurrent allowance for doubtful accounts of $15 million and $0 at respective dates)	2,863	1,978
Total other noncurrent assets	22,424	22,118
TOTAL ASSETS	103,327	97,856
Current Liabilities
Short-term borrowings	2,184	3,547
Long-term debt, classified as current (includes $18 million and $0 related to VIEs at respective dates)	4,481	28
Accounts payable
Trade creditors	2,855	2,402
Regulatory balancing accounts	1,121	1,245
Other	679	580
Operating lease liabilities	468	533
Disputed claims and customer refunds	0	242
Interest payable	481	498
Wildfire-related claims	2,722	2,250
Other	2,436	2,256
Total current liabilities	17,427	13,581
Noncurrent Liabilities
Long-term debt (includes $1.82 billion and $1.0 billion related to VIEs at respective dates)	38,225	37,288
Regulatory liabilities	11,999	10,424
Pension and other postretirement benefits	860	2,444
Asset retirement obligations	5,298	6,412
Deferred income taxes	3,177	1,398
Operating lease liabilities	810	1,208
Other	4,308	3,848
Total noncurrent liabilities	64,677	63,022
Contingencies and Commitments (Notes 14 and 15)
Shareholders' Equity
Common stock, no par value, authorized 3,600,000,000 and 3,600,000,000 shares at respective dates; 1,985,400,540 and 1,984,678,673 shares outstanding at respective dates	35,129	30,224
Treasury Stock, at cost; 477,743,590 and 0 shares at respective dates	(4,854)	0
Reinvested earnings	(9,284)	(9,196)
Accumulated other comprehensive loss	(20)	(27)
Total shareholders' equity	20,971	21,001
Noncontrolling Interest - Preferred Stock of Subsidiary	252	252
Total equity	21,223	21,253
TOTAL LIABILITIES AND EQUITY	$ 103,327	$ 97,856

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Allowance for doubtful accounts	$ 171	$ 146
Customers (net of allowance for doubtful accounts of $171 million and $146 million at respective dates) (includes $2.06 billion and $1.63 billion related to VIEs, net of allowance for doubtful accounts of $171 million and $143 million at respective dates)	2,345	1,883
Accrued unbilled revenue (includes $1.09 billion and $959 million related to VIEs at respective dates)	1,207	1,083
Long-term debt, classified as current (includes $18 million and $0 related to VIEs at respective dates)	4,481	28
Long-term debt (includes $1.82 billion and $1.0 billion related to VIEs at respective dates)	$ 38,225	$ 37,288
Common stock, par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized (in shares)	3,600,000,000	3,600,000,000
Common stock, shares outstanding (in shares)	1,985,400,540	1,984,678,673
Treasury stock, shares at cost (in shares)	477,743,590	0
Variable Interest Entity, Primary Beneficiary
Allowance for doubtful accounts	$ 171	$ 143
Customers (net of allowance for doubtful accounts of $171 million and $146 million at respective dates) (includes $2.06 billion and $1.63 billion related to VIEs, net of allowance for doubtful accounts of $171 million and $143 million at respective dates)	2,060	1,630
Accrued unbilled revenue (includes $1.09 billion and $959 million related to VIEs at respective dates)	1,090	959
Net noncurrent accounts receivable	187,000	0
Noncurrent allowance for doubtful accounts	15,000	0
Long-term debt, classified as current (includes $18 million and $0 related to VIEs at respective dates)	18	0
Long-term debt (includes $1.82 billion and $1.0 billion related to VIEs at respective dates)	$ 1,820	$ 1,000

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash Flows from Operating Activities
Net income (loss)	$ (88)	$ (1,304)	$ (7,642)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	3,403	3,468	3,234
Bad Debt Expense	154	150	46
Allowance for equity funds used during construction	(133)	(140)	(79)
Deferred income taxes and tax credits, net	1,783	1,097	(2,948)
Reorganization items, net (Note 2)	(73)	1,458	108
Wildfire fund expense	517	413	0
Disallowed capital expenditures	0	17	581
Other	248	249	161
Effect of changes in operating assets and liabilities:
Accounts receivable	(589)	(1,182)	(104)
Wildfire-related insurance receivable	(723)	1,564	35
Inventories	(32)	6	(80)
Accounts payable	117	58	516
Wildfire-related claims	472	(16,525)	(114)
Income taxes receivable/payable	0	0	23
Other current assets and liabilities	244	(1,079)	77
Regulatory assets, liabilities, and balancing accounts, net	(2,266)	(2,451)	(1,417)
Liabilities subject to compromise	0	413	12,222
Contributions to Wildfire fund	(193)	(5,200)	0
Other noncurrent assets and liabilities	(579)	(142)	197
Net cash provided by (used in) operating activities	2,262	(19,130)	4,816
Cash Flows from Investing Activities
Capital expenditures	(7,689)	(7,690)	(6,313)
Proceeds from sale of the SFGO	749	0	0
Proceeds from sales and maturities of nuclear decommissioning trust investments	1,678	1,518	956
Purchases of nuclear decommissioning trust investments	(1,702)	(1,590)	(1,032)
Other	59	14	11
Net cash used in investing activities	(6,905)	(7,748)	(6,378)
Cash Flows from Financing Activities
Proceeds from debtor-in-possession credit facility	0	500	1,850
Repayments of debtor-in-possession credit facility	0	(2,000)	(350)
Debtor-in-possession credit facility debt issuance costs	0	(6)	(113)
Bridge facility financing fees	0	(73)	0
Borrowings under credit facilities	9,730	8,554	0
Repayments under credit facilities	(9,976)	(3,949)	0
Credit facilities financing fees	(9)	(22)	0
Short-term debt financing, net of issuance costs of $1, $2, and $0 at respective dates	300	1,448	0
Short-term debt matured	(1,450)	0	0
Proceeds from issuance of long-term debt, net of premium, discount and issuance costs of $43, $178, and $0 at respective dates	5,474	13,497	0
Repayment of long-term debt	(87)	(764)	0
Proceeds from sale of future revenue from transmission tower license sales, net of fees	370	0	0
Exchanged debt financing fees	0	(103)	0
Common stock issued	0	7,582	85
Equity Units issued	0	1,304	0
Other	(29)	(40)	(8)
Net cash provided by financing activities	4,323	25,928	1,464
Net change in cash, cash equivalents, and restricted cash	(320)	(950)	(98)
Cash, cash equivalents, and restricted cash at January 1	627	1,577	1,675
Cash, cash equivalents, and restricted cash at December 31	307	627	1,577
Less: Restricted cash and restricted cash equivalents	(16)	(143)	(7)
Cash and cash equivalents at December 31	291	484	1,570
Cash paid for:
Interest, net of amounts capitalized	(1,404)	(1,563)	(10)
Income taxes, net	99	0	0
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	1,311	515	826
Operating lease liabilities arising from obtaining ROU assets	100	13	2,816
Common stock issued in satisfaction of liabilities	0	8,276	0
Increase to PG&E Corporation common stock and treasury stock in connection with the Share Exchange and Tax Matters Agreement	$ 4,854	$ 0	$ 0

CONSOLIDATED STATEMENTS OF CA_2

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash Flows from Financing Activities
Issuance costs for short-term debt	$ 1	$ 2	$ 0
Premium, discount, and issuance costs on proceeds from long-term debt	$ 43	$ 178	$ 0

CONSOLIDATED STATEMENTS OF EQUI

CONSOLIDATED STATEMENTS OF EQUITY - USD ($) $ in Millions	Total	PG&E ShareCoCommon Stock	Total Shareholders' Equity	Common Stock		Treasury Stock	Reinvested Earnings	Accumulated Other Comprehensive Income (Loss)	Non- controlling Interest - Preferred Stock of Subsidiary
Beginning balance (in shares) at Dec. 31, 2018				520,338,710
Beginning balance at Dec. 31, 2018	$ 12,903		$ 12,651	$ 12,910			$ (250)	$ (9)	$ 252
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(7,642)		(7,642)				(7,642)
Total other comprehensive income (loss)	(1)		(1)					(1)
Common stock issued, net (in shares)				8,898,031
Common stock issued, net	85		85	$ 85
Stock-based compensation amortization	43		43	$ 43
Ending balance (in shares) at Dec. 31, 2019				529,236,741
Ending balance at Dec. 31, 2019	5,388		5,136	$ 13,038			(7,892)	(10)	252
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(1,304)		(1,304)				(1,304)
Total other comprehensive income (loss)	(17)		(17)					(17)
Common stock issued, net (in shares)				1,455,441,932
Common stock issued, net	15,854		15,854	$ 15,854
Equity units issued	1,304		1,304	1,304
Stock-based compensation amortization	$ 28		28	$ 28
Ending balance (in shares) at Dec. 31, 2020	1,984,678,673			1,984,678,673
Ending balance at Dec. 31, 2020	$ 21,253		21,001	$ 30,224			(9,196)	(27)	252
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(88)		(88)				(88)
Total other comprehensive income (loss)	7		7					7
Common stock issued, net (in shares)		477,743,590		721,867	[1]
Common stock issued, net	4,854		4,854	$ 4,854
Treasury stock acquired (in shares)						477,743,590
Treasury stock acquired	(4,854)		(4,854)			$ (4,854)
Stock-based compensation amortization	$ 51		51	$ 51
Ending balance (in shares) at Dec. 31, 2021	1,985,400,540			1,985,400,540		477,743,590
Ending balance at Dec. 31, 2021	$ 21,223		$ 20,971	$ 35,129		$ (4,854)	$ (9,284)	$ (20)	$ 252

[1]	Excludes 477,743,590 shares of common stock issued to ShareCo. For more information, see Note 6 below.

CONSOLIDATED STATEMENTS OF IN_2

CONSOLIDATED STATEMENTS OF INCOME, UTILITY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Revenues
Total operating revenues	$ 20,642	$ 18,469	$ 17,129
Operating Expenses
Operating and maintenance	10,200	8,684	8,725
Wildfire-related claims, net of recoveries	258	251	11,435
Wildfire fund expense	517	413	0
Depreciation, amortization, and decommissioning	3,403	3,468	3,234
Total operating expenses	18,759	16,714	27,223
Operating Income (Loss)	1,883	1,755	(10,094)
Interest income	20	39	82
Interest expense	(1,601)	(1,260)	(934)
Other income, net	457	483	250
Reorganization items, net	(11)	(1,959)	(346)
Income (Loss) Before Income Taxes	748	(942)	(11,042)
Income tax provision (benefit)	836	362	(3,400)
Net Loss	(88)	(1,304)	(7,642)
Loss Attributable to Common Shareholders	(102)	(1,318)	(7,656)
Pacific Gas & Electric Co (Utility)
Operating Revenues
Total operating revenues	20,642	18,469	17,129
Operating Expenses
Operating and maintenance	10,194	8,707	8,750
Wildfire-related claims, net of recoveries	258	251	11,435
Wildfire fund expense	517	413	0
Depreciation, amortization, and decommissioning	3,403	3,469	3,233
Total operating expenses	18,753	16,738	27,247
Operating Income (Loss)	1,889	1,731	(10,118)
Interest income	22	39	82
Interest expense	(1,373)	(1,111)	(912)
Other income, net	512	470	239
Reorganization items, net	(12)	(310)	(320)
Income (Loss) Before Income Taxes	1,038	819	(11,029)
Income tax provision (benefit)	900	408	(3,407)
Net Loss	138	411	(7,622)
Preferred stock dividend requirement	14	14	14
Loss Attributable to Common Shareholders	124	397	(7,636)
Electric
Operating Revenues
Total operating revenues	15,131	13,858	12,740
Operating Expenses
Cost of electricity and natural gas	3,232	3,116	3,095
Electric \| Pacific Gas & Electric Co (Utility)
Operating Revenues
Total operating revenues	15,131	13,858	12,740
Operating Expenses
Cost of electricity and natural gas	3,232	3,116	3,095
Natural gas
Operating Revenues
Total operating revenues	5,511	4,611	4,389
Operating Expenses
Cost of electricity and natural gas	1,149	782	734
Natural gas \| Pacific Gas & Electric Co (Utility)
Operating Revenues
Total operating revenues	5,511	4,611	4,389
Operating Expenses
Cost of electricity and natural gas	$ 1,149	$ 782	$ 734

CONSOLIDATED STATEMENTS OF CO_3

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME, UTILITY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net Loss	$ (88)	$ (1,304)	$ (7,642)
Other Comprehensive Income (Loss)
Pension and other postretirement benefit plans obligations	7	(17)	(1)
Total other comprehensive income (loss)	7	(17)	(1)
Comprehensive Loss	(81)	(1,321)	(7,643)
Pacific Gas & Electric Co (Utility)
Net Loss	138	411	(7,622)
Other Comprehensive Income (Loss)
Pension and other postretirement benefit plans obligations	(4)	(6)	2
Total other comprehensive income (loss)	(4)	(6)	2
Comprehensive Loss	$ 134	$ 405	$ (7,620)

CONSOLIDATED STATEMENTS OF CO_4

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension and other postretirement benefit plans obligations, tax	$ 3	$ 7	$ 0
Pacific Gas & Electric Co (Utility)
Pension and other postretirement benefit plans obligations, tax	$ 1	$ 2	$ 1

CONSOLIDATED BALANCE SHEETS, UT

CONSOLIDATED BALANCE SHEETS, UTILITY - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Current Assets
Cash and cash equivalents	$ 291	$ 484
Restricted Cash	16	143
Accounts receivable
Customers (net of allowance for doubtful accounts of $171 million and $146 million at respective dates) (includes $2.06 billion and $1.63 billion related to VIEs, net of allowance for doubtful accounts of $171 million and $143 million at respective dates)	2,345	1,883
Accrued unbilled revenue (includes $1.09 billion and $959 million related to VIEs at respective dates)	1,207	1,083
Regulatory balancing accounts	2,999	2,001
Other	1,784	1,172
Regulatory assets	496	410
Inventories
Gas stored underground and fuel oil	44	95
Materials and supplies	552	533
Wildfire fund asset	461	464
Other	882	1,334
Total current assets	11,077	9,602
Property, Plant, and Equipment
Electric	69,482	66,982
Gas	25,979	24,135
Construction work in progress	3,479	2,757
Financing lease and other	20	20
Total property, plant, and equipment	98,960	93,894
Accumulated depreciation	(29,134)	(27,758)
Net property, plant, and equipment	69,826	66,136
Other Noncurrent Assets
Regulatory assets	9,207	8,978
Nuclear decommissioning trusts	3,798	3,538
Operating lease right of use asset	1,234	1,741
Wildfire fund asset	5,313	5,816
Income taxes receivable	9	67
Other (includes net noncurrent accounts receivable of $187 million and $0 related to VIEs, net of noncurrent allowance for doubtful accounts of $15 million and $0 at respective dates)	2,863	1,978
Total other noncurrent assets	22,424	22,118
TOTAL ASSETS	103,327	97,856
Current Liabilities
Short-term borrowings	2,184	3,547
Long-term debt, classified as current (includes $18 million and $0 related to VIEs at respective dates)	4,481	28
Accounts payable
Trade creditors	2,855	2,402
Regulatory balancing accounts	1,121	1,245
Other	679	580
Operating lease liabilities	468	533
Disputed claims and customer refunds	0	242
Interest payable	481	498
Wildfire-related claims	2,722	2,250
Other	2,436	2,256
Total current liabilities	17,427	13,581
Noncurrent Liabilities
Long-term debt (includes $1.82 billion and $1.0 billion related to VIEs at respective dates)	38,225	37,288
Regulatory liabilities	11,999	10,424
Pension and other postretirement benefits	860	2,444
Asset retirement obligations	5,298	6,412
Deferred income taxes	3,177	1,398
Operating lease liabilities	810	1,208
Other	4,308	3,848
Total noncurrent liabilities	64,677	63,022
Contingencies and Commitments (Notes 14 and 15)
Shareholders' Equity
Common stock, $5 par value, authorized 800,000,000 shares; 264,374,809 shares outstanding at respective dates	35,129	30,224
Reinvested earnings	(9,284)	(9,196)
Accumulated other comprehensive loss	(20)	(27)
Total shareholders' equity	20,971	21,001
TOTAL LIABILITIES AND EQUITY	103,327	97,856
Pacific Gas & Electric Co (Utility)
Current Assets
Cash and cash equivalents	165	261
Restricted Cash	16	143
Accounts receivable
Customers (net of allowance for doubtful accounts of $171 million and $146 million at respective dates) (includes $2.06 billion and $1.63 billion related to VIEs, net of allowance for doubtful accounts of $171 million and $143 million at respective dates)	2,345	1,883
Accrued unbilled revenue (includes $1.09 billion and $959 million related to VIEs at respective dates)	1,207	1,083
Regulatory balancing accounts	2,999	2,001
Other	1,932	1,180
Regulatory assets	496	410
Inventories
Gas stored underground and fuel oil	44	95
Materials and supplies	552	533
Wildfire fund asset	461	464
Other	869	1,321
Total current assets	11,086	9,374
Property, Plant, and Equipment
Electric	69,482	66,982
Gas	25,979	24,135
Construction work in progress	3,480	2,757
Financing lease and other	18	18
Total property, plant, and equipment	98,959	93,892
Accumulated depreciation	(29,131)	(27,756)
Net property, plant, and equipment	69,828	66,136
Other Noncurrent Assets
Regulatory assets	9,207	8,978
Nuclear decommissioning trusts	3,798	3,538
Operating lease right of use asset	1,232	1,736
Wildfire fund asset	5,313	5,816
Income taxes receivable	7	66
Other (includes net noncurrent accounts receivable of $187 million and $0 related to VIEs, net of noncurrent allowance for doubtful accounts of $15 million and $0 at respective dates)	2,706	1,818
Total other noncurrent assets	22,263	21,952
TOTAL ASSETS	103,177	97,462
Current Liabilities
Short-term borrowings	2,184	3,547
Long-term debt, classified as current (includes $18 million and $0 related to VIEs at respective dates)	4,455	0
Accounts payable
Trade creditors	2,853	2,366
Regulatory balancing accounts	1,121	1,245
Other	648	624
Operating lease liabilities	467	530
Disputed claims and customer refunds	0	242
Interest payable	430	444
Wildfire-related claims	2,722	2,250
Other	2,430	2,248
Total current liabilities	17,310	13,496
Noncurrent Liabilities
Long-term debt (includes $1.82 billion and $1.0 billion related to VIEs at respective dates)	33,632	32,664
Regulatory liabilities	11,999	10,424
Pension and other postretirement benefits	764	2,328
Asset retirement obligations	5,298	6,412
Deferred income taxes	3,409	1,570
Operating lease liabilities	810	1,206
Other	4,345	3,886
Total noncurrent liabilities	60,257	58,490
Contingencies and Commitments (Notes 14 and 15)
Shareholders' Equity
Preferred stock	258	258
Common stock, $5 par value, authorized 800,000,000 shares; 264,374,809 shares outstanding at respective dates	1,322	1,322
Additional paid-in capital	28,286	28,286
Reinvested earnings	(4,247)	(4,385)
Accumulated other comprehensive loss	(9)	(5)
Total shareholders' equity	25,610	25,476
TOTAL LIABILITIES AND EQUITY	$ 103,177	$ 97,462

CONSOLIDATED BALANCE SHEETS (_2

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Allowance for doubtful accounts	$ 171	$ 146
Customers (net of allowance for doubtful accounts of $171 million and $146 million at respective dates) (includes $2.06 billion and $1.63 billion related to VIEs, net of allowance for doubtful accounts of $171 million and $143 million at respective dates)	2,345	1,883
Accrued unbilled revenue (includes $1.09 billion and $959 million related to VIEs at respective dates)	1,207	1,083
Long-term debt, classified as current (includes $18 million and $0 related to VIEs at respective dates)	4,481	28
Long-term debt (includes $1.82 billion and $1.0 billion related to VIEs at respective dates)	$ 38,225	$ 37,288
Common stock, par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized (in shares)	3,600,000,000	3,600,000,000
Common stock, shares outstanding (in shares)	1,985,400,540	1,984,678,673
Pacific Gas & Electric Co (Utility)
Allowance for doubtful accounts	$ 171	$ 146
Customers (net of allowance for doubtful accounts of $171 million and $146 million at respective dates) (includes $2.06 billion and $1.63 billion related to VIEs, net of allowance for doubtful accounts of $171 million and $143 million at respective dates)	2,345	1,883
Accrued unbilled revenue (includes $1.09 billion and $959 million related to VIEs at respective dates)	1,207	1,083
Long-term debt, classified as current (includes $18 million and $0 related to VIEs at respective dates)	4,455	0
Long-term debt (includes $1.82 billion and $1.0 billion related to VIEs at respective dates)	$ 33,632	$ 32,664
Common stock, par value (in dollars per share)	$ 5	$ 5
Common stock, shares authorized (in shares)	800,000,000	800,000,000
Common stock, shares outstanding (in shares)	264,374,809	264,374,809
Variable Interest Entity, Primary Beneficiary
Allowance for doubtful accounts	$ 171	$ 143
Customers (net of allowance for doubtful accounts of $171 million and $146 million at respective dates) (includes $2.06 billion and $1.63 billion related to VIEs, net of allowance for doubtful accounts of $171 million and $143 million at respective dates)	2,060	1,630
Accrued unbilled revenue (includes $1.09 billion and $959 million related to VIEs at respective dates)	1,090	959
Net noncurrent accounts receivable	187,000	0
Noncurrent allowance for doubtful accounts	15,000	0
Long-term debt, classified as current (includes $18 million and $0 related to VIEs at respective dates)	18	0
Long-term debt (includes $1.82 billion and $1.0 billion related to VIEs at respective dates)	1,820	1,000
Variable Interest Entity, Primary Beneficiary \| Pacific Gas & Electric Co (Utility)
Allowance for doubtful accounts	171	143
Customers (net of allowance for doubtful accounts of $171 million and $146 million at respective dates) (includes $2.06 billion and $1.63 billion related to VIEs, net of allowance for doubtful accounts of $171 million and $143 million at respective dates)	2,060	1,630
Accrued unbilled revenue (includes $1.09 billion and $959 million related to VIEs at respective dates)	1,090	959
Net noncurrent accounts receivable	187,000	0
Noncurrent allowance for doubtful accounts	15,000	0
Long-term debt, classified as current (includes $18 million and $0 related to VIEs at respective dates)	18	0
Long-term debt (includes $1.82 billion and $1.0 billion related to VIEs at respective dates)	$ 1,820	$ 1,000

CONSOLIDATED STATEMENTS OF CA_3

CONSOLIDATED STATEMENTS OF CASH FLOWS, UTILITY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash Flows from Operating Activities
Net income (loss)	$ (88)	$ (1,304)	$ (7,642)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	3,403	3,468	3,234
Bad Debt Expense	154	150	46
Allowance for equity funds used during construction	(133)	(140)	(79)
Deferred income taxes and tax credits, net	1,783	1,097	(2,948)
Reorganization items, net (Note 2)	(73)	1,458	108
Wildfire fund expense	517	413	0
Disallowed capital expenditures	0	17	581
Other	248	249	161
Effect of changes in operating assets and liabilities:
Accounts receivable	(589)	(1,182)	(104)
Wildfire-related insurance receivable	(723)	1,564	35
Inventories	(32)	6	(80)
Accounts payable	117	58	516
Wildfire-related claims	472	(16,525)	(114)
Income taxes receivable/payable	0	0	23
Other current assets and liabilities	244	(1,079)	77
Regulatory assets, liabilities, and balancing accounts, net	(2,266)	(2,451)	(1,417)
Liabilities subject to compromise	0	413	12,222
Contributions to Wildfire fund	(193)	(5,200)	0
Other noncurrent assets and liabilities	(579)	(142)	197
Net cash provided by (used in) operating activities	2,262	(19,130)	4,816
Cash Flows from Investing Activities
Capital expenditures	(7,689)	(7,690)	(6,313)
Proceeds from sale of the SFGO	749	0	0
Proceeds from sales and maturities of nuclear decommissioning trust investments	1,678	1,518	956
Purchases of nuclear decommissioning trust investments	(1,702)	(1,590)	(1,032)
Other	59	14	11
Net cash used in investing activities	(6,905)	(7,748)	(6,378)
Cash Flows from Financing Activities
Proceeds from debtor-in-possession credit facility	0	500	1,850
Repayments of debtor-in-possession credit facility	0	(2,000)	(350)
Debtor-in-possession credit facility debt issuance costs	0	(6)	(113)
Bridge facility financing fees	0	(73)	0
Borrowings under credit facilities	9,730	8,554	0
Repayments under credit facilities	(9,976)	(3,949)	0
Credit facilities financing fees	(9)	(22)	0
Short-term debt financing, net of issuance costs of $1, $2, and $0 at respective dates	300	1,448	0
Short-term debt matured	(1,450)	0	0
Proceeds from issuance of long-term debt, net of premium, discount and issuance costs of $43, $178, and $0 at respective dates	5,474	13,497	0
Repayment of long-term debt	(87)	(764)	0
Proceeds from sale of future revenue from transmission tower license sales, net of fees	370	0	0
Exchanged debt financing fees	0	(103)	0
Other	(29)	(40)	(8)
Net cash provided by financing activities	4,323	25,928	1,464
Net change in cash, cash equivalents, and restricted cash	(320)	(950)	(98)
Cash, cash equivalents, and restricted cash at January 1	627	1,577	1,675
Cash, cash equivalents, and restricted cash at December 31	307	627	1,577
Less: Restricted cash and restricted cash equivalents	(16)	(143)	(7)
Cash and cash equivalents at December 31	291	484	1,570
Cash paid for:
Interest, net of amounts capitalized	(1,404)	(1,563)	(10)
Income taxes, net	99	0	0
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	1,311	515	826
Operating lease liabilities arising from obtaining ROU assets	100	13	2,816
Pacific Gas & Electric Co (Utility)
Cash Flows from Operating Activities
Net income (loss)	138	411	(7,622)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	3,403	3,469	3,233
Bad Debt Expense	154	150	46
Allowance for equity funds used during construction	(133)	(140)	(79)
Deferred income taxes and tax credits, net	1,846	1,141	(2,952)
Reorganization items, net (Note 2)	(41)	(90)	97
Wildfire fund expense	517	413	0
Disallowed capital expenditures	0	17	581
Other	172	220	121
Effect of changes in operating assets and liabilities:
Accounts receivable	(584)	(1,160)	(132)
Wildfire-related insurance receivable	(723)	1,564	35
Inventories	(32)	6	(80)
Accounts payable	44	(24)	579
Wildfire-related claims	472	(16,525)	(114)
Income taxes receivable/payable	0	0	5
Other current assets and liabilities	251	(1,141)	101
Regulatory assets, liabilities, and balancing accounts, net	(2,266)	(2,451)	(1,417)
Liabilities subject to compromise	0	401	12,194
Contributions to Wildfire fund	(193)	(5,200)	0
Other noncurrent assets and liabilities	(577)	(108)	214
Net cash provided by (used in) operating activities	2,448	(19,047)	4,810
Cash Flows from Investing Activities
Capital expenditures	(7,689)	(7,690)	(6,313)
Proceeds from sale of the SFGO	749	0	0
Proceeds from sales and maturities of nuclear decommissioning trust investments	1,678	1,518	956
Purchases of nuclear decommissioning trust investments	(1,702)	(1,590)	(1,032)
Intercompany note to PG&E Corporation	(145)	0	0
Other	59	14	11
Net cash used in investing activities	(7,050)	(7,748)	(6,378)
Cash Flows from Financing Activities
Proceeds from debtor-in-possession credit facility	0	500	1,850
Repayments of debtor-in-possession credit facility	0	(2,000)	(350)
Debtor-in-possession credit facility debt issuance costs	0	(6)	(97)
Bridge facility financing fees	0	(33)	0
Borrowings under credit facilities	9,730	8,554	0
Repayments under credit facilities	(9,976)	(3,949)	0
Credit facilities financing fees	(9)	(22)	0
Short-term debt financing, net of issuance costs of $1, $2, and $0 at respective dates	300	1,448	0
Short-term debt matured	(1,450)	0	0
Proceeds from issuance of long-term debt, net of premium, discount and issuance costs of $43, $178, and $0 at respective dates	5,474	8,837	0
Repayment of long-term debt	(59)	(100)	0
Proceeds from sale of future revenue from transmission tower license sales, net of fees	370	0	0
Exchanged debt financing fees	0	(103)	0
Equity contribution from PG&E Corporation	0	12,986	0
Other	(1)	(42)	(8)
Net cash provided by financing activities	4,379	26,070	1,395
Net change in cash, cash equivalents, and restricted cash	(223)	(725)	(173)
Cash, cash equivalents, and restricted cash at January 1	404	1,129	1,302
Cash, cash equivalents, and restricted cash at December 31	181	404	1,129
Less: Restricted cash and restricted cash equivalents	(16)	(143)	(7)
Cash and cash equivalents at December 31	165	261	1,122
Cash paid for:
Interest, net of amounts capitalized	(1,198)	(1,458)	(7)
Income taxes, net	99	0	0
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	1,311	515	826
Operating lease liabilities arising from obtaining ROU assets	100	13	2,807
Common stock equity infusion from PG&E Corporation used to satisfy liabilities	$ 0	$ 6,750	$ 0

CONSOLIDATED STATEMENTS OF CA_4

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash Flows from Financing Activities
Issuance costs for short-term debt	$ 1	$ 2	$ 0
Premium, discount, and issuance costs on proceeds from long-term debt	43	178	0
Pacific Gas & Electric Co (Utility)
Cash Flows from Financing Activities
Issuance costs for short-term debt	1	2	0
Premium, discount, and issuance costs on proceeds from long-term debt	$ 43	$ 88	$ 0

CONSOLIDATED STATEMENTS OF EQ_2

CONSOLIDATED STATEMENTS OF EQUITY, UTILITY - USD ($) $ in Millions	Total	Pacific Gas & Electric Co (Utility)	Total Shareholders' Equity	Total Shareholders' EquityPacific Gas & Electric Co (Utility)	Preferred StockPacific Gas & Electric Co (Utility)	Common Stock	Common StockPacific Gas & Electric Co (Utility)	Additional Paid-in CapitalPacific Gas & Electric Co (Utility)	Reinvested Earnings	Reinvested EarningsPacific Gas & Electric Co (Utility)	Accumulated Other Comprehensive Income (Loss)	Accumulated Other Comprehensive Income (Loss)Pacific Gas & Electric Co (Utility)
Beginning balance at Dec. 31, 2018	$ 12,903		$ 12,651	$ 12,955	$ 258	$ 12,910	$ 1,322	$ 8,550	$ (250)	$ 2,826	$ (9)	$ (1)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(7,642)	$ (7,622)	(7,642)	(7,622)					(7,642)	(7,622)
Total other comprehensive income (loss)	(1)	2	(1)	2							(1)	2
Ending balance at Dec. 31, 2019	5,388		5,136	5,335	258	13,038	1,322	8,550	(7,892)	(4,796)	(10)	1
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(1,304)	411	(1,304)	411					(1,304)	411
Total other comprehensive income (loss)	(17)	(6)	(17)	(6)							(17)	(6)
Equity Contribution				19,736				19,736
Ending balance at Dec. 31, 2020	21,253		21,001	25,476	258	30,224	1,322	28,286	(9,196)	(4,385)	(27)	(5)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(88)	138	(88)	138					(88)	138
Total other comprehensive income (loss)	7	$ (4)	7	(4)							7	(4)
Ending balance at Dec. 31, 2021	$ 21,223		$ 20,971	$ 25,610	$ 258	$ 35,129	$ 1,322	$ 28,286	$ (9,284)	$ (4,247)	$ (20)	$ (9)

ORGANIZATION AND BASIS OF PRESE

ORGANIZATION AND BASIS OF PRESENTATION	12 Months Ended
ORGANIZATION AND BASIS OF PRESENTATION	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
ORGANIZATION AND BASIS OF PRESENTATION	ORGANIZATION AND BASIS OF PRESENTATION Organization and Basis of Presentation PG&E Corporation is a holding company whose primary operating subsidiary is Pacific Gas and Electric Company, a public utility serving northern and central California. The Utility generates revenues mainly through the sale and delivery of electricity and natural gas to customers. The Utility is primarily regulated by the CPUC and the FERC. In addition, the NRC oversees the licensing, construction, operation, and decommissioning of the Utility’s nuclear generation facilities. This is a combined annual report of PG&E Corporation and the Utility. PG&E Corporation’s Consolidated Financial Statements include the accounts of PG&E Corporation, the Utility, and other wholly owned and controlled subsidiaries. The Utility’s Consolidated Financial Statements include the accounts of the Utility and its wholly owned and controlled subsidiaries. All intercompany transactions have been eliminated in consolidation. The Notes to the Consolidated Financial Statements apply to both PG&E Corporation and the Utility. PG&E Corporation and the Utility assess financial performance and allocate resources on a consolidated basis (i.e., the companies operate in one segment). The accompanying Consolidated Financial Statements have been prepared in conformity with GAAP and in accordance with the reporting requirements of Form 10-K. The preparation of financial statements in conformity with GAAP requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Some of the more significant estimates and assumptions relate to the Utility’s regulatory assets and liabilities, wildfire-related liabilities, legal and regulatory contingencies, the Wildfire Fund, environmental remediation liabilities, AROs, wildfire-related receivables, and pension and other post-retirement benefit plan obligations. Management believes that its estimates and assumptions reflected in the Consolidated Financial Statements are appropriate and reasonable. A change in management’s estimates or assumptions could result in an adjustment that would have a material impact on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows during the period in which such change occurred.

BANKRUPTCY FILING

BANKRUPTCY FILING	12 Months Ended
BANKRUPTCY FILING	Dec. 31, 2021
Reorganizations [Abstract]
BANKRUPTCY FILING	BANKRUPTCY FILING Chapter 11 Proceedings On the Petition Date, PG&E Corporation and the Utility commenced the Chapter 11 Cases with the Bankruptcy Court. Prior to the Emergence Date, PG&E Corporation and the Utility continued to operate their business as debtors-in-possession under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code and orders of the Bankruptcy Court. On June 20, 2020, the Bankruptcy Court entered the Confirmation Order confirming the Plan filed on June 19, 2020. PG&E Corporation and the Utility emerged from Chapter 11 on the Emergence Date of July 1, 2020. Except as otherwise set forth in the Plan, the Confirmation Order or another order of the Bankruptcy Court, substantially all pre-petition liabilities were discharged under the Plan. Unresolved Chapter 11 Claims PG&E Corporation and the Utility have received over 100,000 proofs of claim since the Petition Date, of which approximately 80,000 were channeled to a trust for the benefit of holders of certain subrogation claims (the “Subrogation Wildfire Trust”) and Fire Victim Trust. The claims channeled to the Subrogation Wildfire Trust and Fire Victim Trust will be resolved by such trusts, and PG&E Corporation and the Utility have no further liability in connection with such claims. PG&E Corporation and the Utility continue their review and analysis of certain remaining claims, including asserted litigation claims, trade creditor claims, along with other tax and regulatory claims, and therefore the ultimate liability of PG&E Corporation or the Utility for such claims may differ from the amounts asserted in such claims. Allowed claims are paid in accordance with the Plan and the Confirmation Order. Amounts expected to be allowed are reflected as current liabilities in the Consolidated Balance Sheets. Holders of certain claims may assert that they are entitled under the Plan or the Bankruptcy Code to pursue, or continue to pursue, their claims against PG&E Corporation and the Utility on or after the Emergence Date, including claims arising from or relating to indemnification or contribution claims, including with respect to the wildfire that began on November 8, 2018 near the city of Paradise, Butte County, California (the “2018 Camp fire”), the 2017 Northern California wildfires, and the wildfire that began September 9, 2015 in Amador and Calaveras counties in Northern California (the “2015 Butte fire”). In addition, Subordinated Debt Claims and HoldCo Rescission or Damage Claims (each as defined in Note 14 below) continue to be pursued against PG&E Corporation and the Utility in the claims reconciliation process in the Bankruptcy Court, and claims against certain former directors and current and former officers, as well as certain underwriters, are being pursued in the purported securities class action that is further described in Note 14 under the heading “Securities Class Action Litigation.” In addition to filing objections in the Bankruptcy Court to claims with respect to which PG&E Corporation and the Utility do not believe they have liability, PG&E Corporation and the Utility are working to resolve certain disputed general unsecured claims before a panel of mediators. On November 4, 2021, the Bankruptcy Court entered an order extending the deadline for PG&E Corporation and the Utility to object to claims to June 21, 2022, except for a claim filed by the California Department of Water Resources, for which the Bankruptcy Court set an objection deadline of March 23, 2022. Various electricity suppliers filed claims in the Utility’s 2001 prior proceeding filed under Chapter 11 of the Bankruptcy Code seeking payment for energy supplied to the Utility’s customers between May 2000 and June 2001. While the FERC and judicial proceedings were pending, the Utility pursued settlements with electricity suppliers and entered into a number of settlement agreements with various electricity suppliers to resolve some of these disputed claims and recover on the Utility’s refund claims against these electricity suppliers. After the Utility received $145 million from the California Power Exchange and various escrows that were established as part of the disputed claims settlements in December 2021, the Utility filed at the Bankruptcy Court to close out its 2001 bankruptcy case. On December 22, 2021, the Bankruptcy Court granted the motion for entry of final decree and closed the 2001 bankruptcy case. As of December 31, 2021, the Consolidated Balance Sheets reflected $0 in net claims within Disputed claims and customer refunds compared to $242 million as of December 31, 2020. The Utility expects to refund current regulatory liabilities of $422 million, reflected in Current liabilities – other on the Consolidated Balance Sheets, $145 million of which would be funded from the amounts received from the California Power Exchange and various escrows discussed above. Reorganization Items, Net Reorganization items, net, represent amounts incurred after the Petition Date as a direct result of the Chapter 11 Cases and are comprised of professional fees and financing costs, net of interest income and other. Cash paid for reorganization items, net was $31 million and $53 million for PG&E Corporation and the Utility, respectively, for the year ended December 31, 2021 as compared to $102 million and $400 million fo r PG&E Corporation and the Utility, respectively, during 2020. Reorganization items, net for the year ended December 31, 2021 include the following: Year Ended December 31, 2021 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ — $ — $ — Legal and other 21 (1) 20 Interest and other (9) — (9) Total reorganization items, net $ 12 $ (1) $ 11 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. Reorganization items, net for the year ended December 31, 2020 include the following: Year Ended December 31, 2020 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 6 $ — $ 6 Legal and other (2) 318 1,651 1,969 Interest income (14) (2) (16) Total reorganization items, net $ 310 $ 1,649 $ 1,959 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) Amount includes $1.5 billion in equity backstop premium expense and bridge loan facility fees. Reorganization items, net from the Petition Date through December 31, 2019 include the following: Petition Date Through December 31, 2019 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 97 $ 17 $ 114 Legal and other 273 19 292 Interest income (50) (10) (60) Total reorganization items, net $ 320 $ 26 $ 346 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	Dec. 31, 2021
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Regulation and Regulated Operations The Utility follows accounting principles for rate-regulated entities and collects rates from customers to recover “revenue requirements” that have been authorized by the CPUC or the FERC based on the Utility’s cost of providing service. The Utility’s ability to recover a significant portion of its authorized revenue requirements through rates is generally independent, or “decoupled,” from the volume of the Utility’s electricity and natural gas sales. The Utility records assets and liabilities that result from the regulated ratemaking process that would not be recorded under GAAP for nonregulated entities. The Utility capitalizes and records, as regulatory assets, costs that would otherwise be charged to expense if it is probable that the incurred costs will be recovered through future rates. Regulatory assets are amortized over the future periods in which the costs are recovered. If costs expected to be incurred in the future are currently being recovered through rates, the Utility records those expected future costs as regulatory liabilities. Amounts that are probable of being credited or refunded to customers in the future are also recorded as regulatory liabilities. The Utility also records a regulatory balancing account asset or liability for differences between customer billings and authorized revenue requirements that are probable of recovery or refund. In addition, the Utility records a regulatory balancing account asset or liability for differences between incurred costs and customer billings or authorized revenue meant to recover those costs, to the extent that these differences are probable of recovery or refund. These differences have no impact on net income. See “Revenue Recognition” below. Management continues to believe the use of regulatory accounting is applicable and that all regulatory assets and liabilities are recoverable or refundable. To the extent that portions of the Utility’s operations cease to be subject to cost of service rate regulation, or recovery is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are written off. Cash, Cash Equivalents, and Restricted Cash Cash and cash equivalents consist of cash and short-term, highly liquid investments with original maturities of three months or less. Cash equivalents are stated at fair value. As of December 31, 2020, the Utility also held restricted cash that primarily consisted of cash held in escrow to be used to pay bankruptcy related professional fees. Revenue Recognition Revenue from Contracts with Customers The Utility recognizes revenues when electricity and natural gas services are delivered. The Utility records unbilled revenues for the estimated amount of energy delivered to customers but not yet billed at the end of the period. Unbilled revenues are included in accounts receivable on the Consolidated Balance Sheets. Rates charged to customers are based on CPUC and FERC authorized revenue requirements. Revenues can vary significantly from period to period because of seasonality, weather, and customer usage patterns. Regulatory Balancing Account Revenue The CPUC authorizes most of the Utility’s revenues in the Utility’s GRCs, which occur every four years. The Utility's ability to recover revenue requirements authorized by the CPUC in these rate cases is independent or “decoupled” from the volume of the Utility's sales of electricity and natural gas services. The Utility recognizes revenues that have been authorized for rate recovery, are objectively determinable and probable of recovery, and are expected to be collected within 24 months. Generally, electric and natural gas operating revenue is recognized ratably over the year. The Utility records a balancing account asset or liability for differences between customer billings and authorized revenue requirements that are probable of recovery or refund. The Utility also collects additional revenue requirements to recover costs that the CPUC has authorized the Utility to pass on to customers, including costs to purchase electricity and natural gas, and to fund public purpose, demand response, and customer energy efficiency programs. In general, the revenue recognition criteria for pass-through costs billed to customers are met at the time the costs are incurred. The Utility records a regulatory balancing account asset or liability for differences between incurred costs and customer billings or authorized revenue meant to recover those costs, to the extent that these differences are probable of recovery or refund. As a result, these differences have no impact on net income. The following table presents the Utility’s revenues disaggregated by type of customer: Year Ended (in millions) 2021 2020 Electric Revenue from contracts with customers Residential $ 6,089 $ 5,523 Commercial 5,042 4,722 Industrial 1,493 1,530 Agricultural 1,565 1,471 Public street and highway lighting 73 69 Other (1) (84) (130) Total revenue from contracts with customers - electric 14,178 13,185 Regulatory balancing accounts (2) 953 673 Total electric operating revenue $ 15,131 $ 13,858 Natural gas Revenue from contracts with customers Residential $ 2,759 $ 2,517 Commercial 713 597 Transportation service only 1,346 1,211 Other (1) 140 61 Total revenue from contracts with customers - gas 4,958 4,386 Regulatory balancing accounts (2) 553 225 Total natural gas operating revenue 5,511 4,611 Total operating revenues $ 20,642 $ 18,469 (1) This activity is primarily related to the change in unbilled revenue and amounts subject to refund, partially offset by other miscellaneous revenue items. (2) These amounts represent revenues authorized to be billed or refunded to customers. Financial Assets Measured at Amortized Cost – Credit Losses PG&E Corporation and the Utility use the current expected credit loss model to estimate the expected lifetime credit loss on financial assets measured at amortized cost. PG&E Corporation and the Utility evaluate credit risk in their portfolio of financial assets quarterly. As of December 31, 2021, PG&E Corporation and the Utility have identified the following significant categories of financial assets. Trade Receivables Trade receivables are represented by customer accounts. PG&E Corporation and the Utility record an allowance for doubtful accounts to recognize an estimate of expected lifetime credit losses. The allowance is determined on a collective basis based on the historical amounts written-off and an assessment of customer collectability. Furthermore, economic conditions are evaluated as part of the estimate of expected lifetime credit losses using an analysis of regional unemployment rates. As of December 31, 2021, the allowance also included the estimated impact of the CAPP which offers financial assistance from the State of California for eligible customers in the form of a credit to the customer’s bill. The Utility recorded a reduction to the allowance for doubtful accounts of approximately $207 million in the fourth quarter of 2021 as a result of the expected CAPP funding, which was received on January 27, 2022. As of December 31, 2021, the Utility recorded $209 million of long-term accounts receivables as a result of the CPUC’s June 30, 2021 final decision on bill debt relief which offers financial assistance for eligible customers in the form of a 24-month payment plan. As of December 31, 2021, expected credit losses of $154 million were recorded in Operating and maintenance expense on the Consolidated Statements of Income for credit losses associated with trade and other receivables. The portion of expected credit losses that are deemed probable of recovery are deferred to the RUBA, CPPMA and a FERC regulatory asset. At December 31, 2021, the RUBA current balancing accounts receivable balance was $127 million, and CPPMA and FERC long-term regulatory asset balances were $30 million and $12 million, respectively. Other Receivables and Available-For-Sale Debt Securities Insurance receivables are related to the liability insurance policies PG&E Corporation and the Utility carry. Insurance receivable risk is related to each insurance carrier’s risk of defaulting on their individual policies. Wildfire fund receivables are the funds available from the statewide fund established under AB 1054 for payment of eligible claims related to the 2021 Dixie fire that exceed $1.0 billion and available insurance coverage. For more information, see Note 14 below. Wildfire fund receivables risk is related to the Wildfire Fund’s durability, which is a measurement of the claim-paying capacity. Lastly, PG&E Corporation and the Utility are required to determine if the fair value is below the amortized cost basis for its available-for-sale debt securities. An impairment may exist if there is an intent to sell or a requirement to sell before recovery of the amortized basis. If such an impairment exists, then PG&E Corporation and the Utility must determine whether a portion of the impairment is a result of expected credit loss. As of December 31, 2021, expected credit losses for insurance receivables, Wildfire Fund receivables, and available-for-sale debt securities were immaterial. Inventories Inventories are carried at weighted-average cost and include natural gas stored underground as well as materials and supplies. Natural gas stored underground is recorded to inventory when injected and then expensed as the gas is withdrawn for distribution to customers or to be used as fuel for electric generation. Materials and supplies are recorded to inventory when purchased and expensed or capitalized to plant, as appropriate, when consumed or installed. Emission Allowances The Utility purchases GHG emission allowances to satisfy its compliance obligations. Associated costs are recorded as inventory and included in current assets – other and other noncurrent assets – other on the Consolidated Balance Sheets. Costs are carried at weighted-average and are recoverable through rates. Property, Plant, and Equipment Property, plant, and equipment are reported at the lower of their historical cost less accumulated depreciation or fair value. Historical costs include labor and materials, construction overhead, and AFUDC. See “AFUDC” below. The Utility’s estimated service lives of its property, plant, and equipment were as follows: Estimated Service Balance at December 31, (in millions, except estimated service lives) Lives (years) 2021 2020 Electricity generating facilities (1) 5 to 75 $ 11,217 $ 12,505 Electricity distribution facilities 10 to 70 37,723 34,902 Electricity transmission facilities 15 to 75 15,516 14,414 Natural gas distribution facilities 20 to 60 14,100 12,962 Natural gas transmission and storage facilities 5 to 66 9,067 8,293 Financing lease 18 18 Construction work in progress 3,480 2,757 General plant and other 5 to 50 7,838 8,041 Total property, plant, and equipment 98,959 93,892 Accumulated depreciation (29,131) (27,756) Net property, plant, and equipment (2) $ 69,828 $ 66,136 (1) Balance includes nuclear fuel inventories. Stored nuclear fuel inventory is stated at weighted-average cost. Nuclear fuel in the reactor is expensed as it is used based on the amount of energy output. See Note 15 below. (2) Includes $850 million of fire risk mitigation-related property, plant, and equipment securitized in accordance with AB 1054. See Note 5 below. The Utility depreciates property, plant, and equipment using the composite, or group, method of depreciation, in which a single depreciation rate is applied to the gross investment balance in a particular class of property, with the exception of its securitized property, plant and equipment, which is depreciated over the life of the bond and a pattern consistent with principal payments. This method approximates the straight-line method of depreciation over the useful lives of property, plant, and equipment. The Utility’s composite depreciation rates were 3.82% in 2021, 3.76% in 2020, and 3.80% in 2019. The useful lives of the Utility’s property, plant, and equipment are authorized by the CPUC and the FERC, and the depreciation expense is recovered through rates charged to customers. Depreciation expense includes a component for the original cost of assets and a component for estimated cost of future removal, net of any salvage value at retirement. Upon retirement, the original cost of the retired assets, net of salvage value, is charged against accumulated depreciation. The cost of repairs and maintenance, including planned major maintenance activities and minor replacements of property, is charged to operating and maintenance expense as incurred. AFUDC AFUDC represents the estimated costs of debt (i.e., interest) and equity funds used to finance regulated plant additions before they go into service and is capitalized as part of the cost of construction. AFUDC is recoverable through rates over the life of the related property once the property is placed in service. AFUDC related to the cost of debt is recorded as a reduction to interest expense. AFUDC related to the cost of equity is recorded in other income. The Utility recorded AFUDC related to debt and equity, respectively, of $56 million and $133 million during 2021, $35 million and $140 million during 2020, and $55 million and $79 million during 2019. Asset Retirement Obligations The following table summarizes the changes in ARO liability during 2021 and 2020, including nuclear decommissioning obligations: (in millions) 2021 2020 ARO liability at beginning of year $ 6,412 $ 5,854 Liabilities incurred in the current period — 268 Revision in estimated cash flows (1,378) 53 Accretion 287 265 Liabilities settled (23) (28) ARO liability at end of year $ 5,298 $ 6,412 The Utility has not recorded a liability related to certain AROs for assets that are expected to operate in perpetuity. As the Utility cannot estimate a settlement date or range of potential settlement dates for these assets, reasonable estimates of fair value cannot be made. As such, ARO liabilities are not recorded for retirement activities associated with substations, certain hydroelectric facilities; removal of lead-based paint in some facilities and certain communications equipment from leased property; and restoration of land to the conditions under certain agreements. Nuclear Decommissioning Obligation Detailed studies of the cost to decommission the Utility’s nuclear generation facilities are generally conducted every three years in conjunction with the Nuclear Decommissioning Cost Triennial Proceeding. In December 2021, the Utility submitted its updated decommissioning cost estimate to the CPUC and correspondingly decreased its ARO liabilities by $1.4 billion. The adjustment was a result of a decrease in estimated costs based on refinements to the site-specific decommissioning analysis. The decommissioning cost estimates are based on the plant location and cost characteristics for the Utility's nuclear power plants. Actual decommissioning costs may vary from these estimates as a result of changes in assumptions such as decommissioning dates; regulatory requirements; technology; and costs of labor, materials, and equipment. The Utility recovers its revenue requirements for decommissioning costs through rates through a non-bypassable charge that the Utility expects will continue until those costs are fully recovered. The total nuclear decommissioning obligation accrued was $3.9 billion and $5.1 billion at December 31, 2021 and 2020, respectively. The estimated undiscounted nuclear decommissioning cost for the Utility’s nuclear power plants was $7.6 billion and $10.6 billion at December 31, 2021 and 2020, respectively. Disallowance of Plant Costs PG&E Corporation and the Utility record a charge when it is both probable that costs incurred or projected to be incurred for recently completed plant will not be recoverable through rates charged to customers and the amount of disallowance can be reasonably estimated. Nuclear Decommissioning Trusts The Utility’s nuclear generation facilities consist of two units at Diablo Canyon and one retired facility at Humboldt Bay. Nuclear decommissioning requires the safe removal of a nuclear generation facility from service and the reduction of residual radioactivity to a level that permits termination of the NRC license and release of the property for unrestricted use. The Utility's nuclear decommissioning costs are recovered through rates and are held in trusts until authorized for release by the CPUC. The Utility classifies its debt investments held in the nuclear decommissioning trusts as available-for-sale. Since the Utility’s nuclear decommissioning trust assets are managed by external investment managers, the Utility does not have the ability to sell its investments at its discretion. Therefore, all unrealized losses are considered other-than-temporary impairments. Gains or losses on the nuclear decommissioning trust investments are refundable or recoverable, respectively, from customers through rates. Therefore, trust earnings are deferred and included in the regulatory liability for recoveries in excess of the ARO. There is no impact on the Utility’s earnings or accumulated other comprehensive income. The cost of debt and equity securities sold by the trust is determined by specific identification. Variable Interest Entities A VIE is an entity that does not have sufficient equity at risk to finance its activities without additional subordinated financial support from other parties, or whose equity investors lack any characteristics of a controlling financial interest. An enterprise that has a controlling financial interest in a VIE is a primary beneficiary and is required to consolidate the VIE. Consolidated VIEs Receivables Securitization Program The SPV created in connection with the Receivables Securitization Program (as defined below in Note 5 below) in October 2020 is a bankruptcy remote, limited liability company wholly owned by the Utility, and its assets are not available to creditors of PG&E Corporation or the Utility. Pursuant to the Receivables Securitization Program, the Utility sells certain of its receivables and certain related rights to payment and obligations of the Utility with respect to such receivables, and certain other related rights to the SPV, which, in turn, obtains loans secured by the receivables from financial institutions (the “Lenders”). Amounts received from the Lenders, the pledged receivables and the corresponding debt are included in Accounts receivable, Other noncurrent assets, and Long-term debt, respectively, on the Consolidated Balance Sheets. As of December 31, 2021, the aggregate principal amount of the loans made by the Lenders cannot exceed $1.0 billion outstanding at any time. On September 15, 2021, the Receivables Securitization Program was amended and extended to September 15, 2023. The SPV is considered a VIE because its equity capitalization is insufficient to support its activities. The most significant activities that impact the economic performance of the SPV are decisions made to manage receivables. The Utility is considered the primary beneficiary and consolidates the SPV as it makes these decisions. No additional financial support was provided to the SPV during the year ended December 31, 2021 or is expected to be provided in the future that was not previously contractually required. As of December 31, 2021 and 2020, the SPV had net accounts receivable of $3.3 billion and $2.6 billion, respectively, and outstanding borrowings of $974 million and $1.0 billion, respectively, under the Receivables Securitization Program. AB 1054 Securitization PG&E Recovery Funding LLC is a bankruptcy remote, limited liability company wholly owned by the Utility, and its assets are not available to creditors of PG&E Corporation or the Utility. Pursuant to the Financing Order for AB 1054, the Utility sold its right to receive revenues from the non-bypassable wildfire hardening fixed recovery charge (“Recovery Property”) to PG&E Recovery Funding LLC, which, in turn, issued recovery bonds secured by the Recovery Property. On November 12, 2021, PG&E Recovery Funding LLC issued approximately $860 million of senior secured recovery bonds. The recovery bonds were issued in three tranches: (1) approximately $266 million with an interest rate of 1.46% and is due July 15, 2033, (2) approximately $160 million with an interest rate of 2.28% and is due January 15, 2038, and (3) approximately $434 million with an interest rate of 2.82% and is due July 15, 2048. The recovery bonds are scheduled to pay principal and interest semi-annually on January 15 and July 15 of each year. The final scheduled payment date is July 15, 2046. Amounts owed to bond-holders are included in Long-term debt and Long-term debt, classified as current, on the Consolidated Balance Sheets. PG&E Recovery Funding LLC is considered a VIE because its equity capitalization is insufficient to support its operations. The most significant activities that impact the economic performance of PG&E Recovery Funding LLC are decisions made by the servicer of the Recovery Property. The Utility is considered the primary beneficiary and consolidates PG&E Recovery Funding LLC as it acts in this role as servicer. No additional financial support was provided to PG&E Recovery Funding LLC during the year ended December 31, 2021 or is expected to be provided in the future that was not previously contractually required. As of December 31, 2021, PG&E Recovery Funding LLC has outstanding borrowings of $860 million. Non-Consolidated VIEs Some of the counterparties to the Utility’s power purchase agreements are considered VIEs. Each of these VIEs was designed to own a power plant that would generate electricity for sale to the Utility. To determine whether the Utility was the primary beneficiary of any of these VIEs at December 31, 2021, it assessed whether it absorbs any of the VIE’s expected losses or receives any portion of the VIE’s expected residual returns under the terms of the power purchase agreement, analyzed the variability in the VIE’s gross margin, and considered whether it had any decision-making rights associated with the activities that are most significant to the VIE’s performance, such as dispatch rights and operating and maintenance activities. The Utility’s financial obligation is limited to the amount the Utility pays for delivered electricity and capacity. The Utility did not have any decision-making rights associated with any of the activities that are most significant to the economic performance of any of these VIEs. Since the Utility was not the primary beneficiary of any of these VIEs at December 31, 2021, it did not consolidate any of them. Initial and Annual Contributions to the Wildfire Fund Established Pursuant to AB 1054 The Wildfire Fund is expected to be capitalized with (i) $10.5 billion of proceeds of bonds supported by a 15-year extension of the Department of Water Resources charge to customers, (ii) $7.5 billion in initial contributions from California’s three large electric IOUs and (iii) $300 million in annual contributions paid by California’s three large electric IOUs for a 10-year period. The contributions from the IOUs will be effectively borne by their respective shareholders, as they will not be permitted to recover these costs through rates. The costs of the initial and annual contributions are allocated among the IOUs pursuant to a “Wildfire Fund allocation metric” set forth in AB 1054 based on land area in the applicable IOU’s service territory classified as HFTDs and adjusted to account for risk mitigation efforts. The Utility’s Wildfire Fund allocation metric is 64.2% (representing an initial contribution of approximately $4.8 billion and annual contributions of approximately $193 million). On the Emergence Date, PG&E Corporation and the Utility contributed, in accordance with AB 1054, an initial contribution of approximately $4.8 billion and first annual contribution of approximately $193 million to the Wildfire Fund to secure participation of the Utility therein. San Diego Gas & Electric Company and Southern California Edison made their initial contributions to the Wildfire Fund in September 2019. On December 30, 2020 and 2021, the Utility made its second and third annual contributions of $193 million each to the Wildfire Fund. As of December 31, 2021, PG&E Corporation and the Utility have seven remaining annual contributions of $193 million (based on the current Wildfire Fund allocation metric). PG&E Corporation and the Utility account for the contributions to the Wildfire Fund similarly to prepaid insurance with expense being allocated to periods ratably based on an estimated period of coverage. As of December 31, 2021, PG&E Corporation and the Utility recorded $193 million in Other current liabilities, $1.1 billion in Other non-current liabilities, $461 million in current assets - Wildfire fund asset, and $5.3 billion in non-current assets - Wildfire fund asset in the Consolidated Balance Sheets. As of December 31, 2021 and December 31, 2020, the Utility recorded amortization and accretion expense of $517 million and $413 million, respectively. The amortization of the asset, accretion of the liability, and acceleration of the amortization of the asset is reflected in Wildfire Fund expense in the Consolidated Statements of Income. Expected contributions recorded in Wildfire Fund asset on the Consolidated Balance Sheets are discounted to the present value using the 10-year U.S. treasury rate at the date PG&E Corporation and the Utility satisfied all the eligibility requirements to participate in the Wildfire Fund. A useful life of 15 years is being used to amortize the Wildfire Fund asset. AB 1054 did not specify a period of coverage; therefore, this accounting treatment is subject to significant accounting judgments and estimates. In estimating the period of coverage, PG&E Corporation and the Utility use a Monte Carlo simulation that began with 12 years of historical, publicly available fire-loss data from wildfires caused by electrical equipment, and subsequently plan to add an additional year of data each following year. The period of historic fire-loss data and the effectiveness of mitigation efforts by the California electric utility companies are significant assumptions used to estimate the useful life. These assumptions along with the other assumptions below create a high degree of uncertainty related to the estimated useful life of the Wildfire Fund. The simulation creates annual distributions of potential losses due to fires that could be attributed to the participating electric utilities. Starting with a five Other assumptions used to estimate the useful life include the estimated cost of wildfires caused by other electric utilities, the amount at which wildfire claims would be settled, the likely adjudication of the CPUC in cases of electric utility-caused wildfires and determination of any amounts required to be reimbursed to the Wildfire Fund, the impacts of climate change, the level of future insurance coverage held by the electric utilities, the FERC-allocable portion of loss recovery, and the future transmission and distribution equity rate base growth of other electric utilities. Significant changes in any of these estimates could materially impact the amortization period. Other Accounting Policies For other accounting policies impacting PG&E Corporation’s and the Utility’s Consolidated Financial Statements, see “Income Taxes” in Note 9, “Derivatives” in Note 10, “Fair Value Measurements” in Note 11, and “Contingencies and Commitments” in Notes 14 and 15 below. Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income The changes, net of income tax, in PG&E Corporation’s accumulated other comprehensive income (loss) for the year ended December 31, 2021 consisted of the following: (in millions, net of income tax) Pension Other Total Beginning balance $ (39) $ 17 $ (22) Other comprehensive income before reclassifications: Unrecognized net actuarial gain (net of taxes of $391 and $53, respectively) 1,007 137 1,144 Regulatory account transfer (net of taxes of $390 and $53, respectively) (1,003) (136) (1,139) Amounts reclassified from other comprehensive income: Amortization of prior service cost (net of taxes of $2 and $4, respectively) (1) (4) 10 6 Amortization of net actuarial (gain) loss (net of taxes of $2 and $9, respectively) (1) 4 (24) (20) Regulatory account transfer (net of taxes of $1 and $5, respectively) (1) 2 14 16 Net current period other comprehensive income 6 1 7 Ending balance $ (33) $ 18 $ (15) (1) These components are included in the computation of net periodic pension and other postretirement benefit costs. See Note 12 below for additional details. The changes, net of income tax, in PG&E Corporation’s accumulated other comprehensive income (loss) for the year ended December 31, 2020 consisted of the following: (in millions, net of income tax) Pension Other Total Beginning balance $ (22) $ 17 $ (5) Other comprehensive income before reclassifications: Unrecognized net actuarial gain (loss) (net of taxes of $162 and $66, respectively) (417) 170 (247) Regulatory account transfer (net of taxes of $155 and $66, respectively) 400 (170) 230 Amounts reclassified from other comprehensive income: Amortization of prior service cost (net of taxes of $2 and $4, respectively) (1) (4) 10 6 Amortization of net actuarial (gain) loss (net of taxes of $1 and $6, respectively) (1) 2 (15) (13) Regulatory account transfer (net of taxes of $1 and $2, respectively) (1) 2 5 7 Net current period other comprehensive loss (17) — (17) Ending balance $ (39) $ 17 $ (22) (1) These components are included in the computation of net periodic pension and other postretirement benefit costs. See Note 12 below for additional details. Recognition of Lease Assets and Liabilities A lease exists when an arrangement allows the lessee to control the use of an identified asset for a stated period in exchange for payments. This determination is made at inception of the arrangement. All leases must be recognized as a ROU asset and a lease liability on the balance sheet of the lessee. The ROU asset reflects the lessee’s right to use the underlying asset for the lease term and the lease liability reflects the obligation to make the lease payments. PG&E Corporation and the Utility have elected not to separate lease and non-lease components. The Utility estimates the ROU assets and lease liabilities at net present value using its incremental secured borrowing rates, unless the implicit discount rate in the leasing arrangement can be ascertained. The incremental secured borrowing rate is based on observed market data and other information available at the lease commencement date. The ROU assets and lease liabilities only include the fixed lease payments for arrangements with terms greater than 12 months. These amounts are presented within the supplemental disclosures of noncash activities on the Consolidated Statement of Cash Flows. Renewal and termination options only impact the lease term if it is reasonably certain that they will be exercised. PG&E Corporation recognizes lease expense on a straight-line basis over the lease term. The Utility recognizes lease expense in conformity with ratemaking. Operating leases are included in operating lease ROU assets and current and noncurrent operating lease liabilities on the Consolidated Balance Sheets. Financing leases are included in property, plant, and equipment, other current liabilities, and other noncurrent liabilities on the Consolidated Balance Sheets. Financing leases were immaterial for the years ended December 31, 2021 and 2020. For the years ended December 31, 2021 and 2020, the Utility made total cash payments, including fixed and variable, of $2.4 billion and $2.5 billion, respectively, for operating leases which are presented within operating activities on the Consolidated Statement of Cash Flows. The fixed cash payments for the principal portion of the financing lease liabilities are immaterial and continue to be included within financing activities on the Consolidated Statement of Cash Flows. Any variable lease payments for financing leases are included in operating activities on the Consolidated Statement of Cash Flows. The majority of the Utility’s ROU assets and lease liabilities relate to various power purchase agreements. These power purchase agreements primarily consist of generation plan

REGULATORY ASSETS, LIABILITIES,

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	12 Months Ended
REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	Dec. 31, 2021
Regulated Operations [Abstract]
REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS Regulatory Assets Long-term regulatory assets are comprised of the following: Balance at December 31, Recovery (in millions) 2021 2020 Pension benefits (1) $ 708 $ 2,245 Indefinitely Environmental compliance costs 1,089 1,112 32 years Utility retained generation (2) 133 181 6 years Price risk management 216 204 19 years Unamortized loss, net of gain, on reacquired debt 37 49 23 years Catastrophic event memorandum account (3) 1,119 842 1 - 3 years Wildfire expense memorandum account (4) 347 400 TBD years Fire hazard prevention memorandum account (5) 75 137 1 - 3 years Fire risk mitigation memorandum account (6) 44 66 1 - 3 years Wildfire mitigation plan memorandum account (7) 424 390 1 - 3 years Deferred income taxes (8) 1,849 908 51 years Insurance premium costs (9) 207 294 3 - 4 years Wildfire mitigation balancing account (10) 273 156 1 - 3 years General rate case memorandum accounts (11) — 376 1 - 2 years Vegetation management balancing account (12) 1,411 592 1 - 3 years COVID-19 pandemic protection memorandum accounts (13) 49 84 TBD years Other 1,226 942 Various Total long-term regulatory assets $ 9,207 $ 8,978 (1) Payments into the pension and other benefits plans are based on annual contribution requirements. As these annual requirements continue indefinitely into the future, the Utility expects to continuously recover pension benefits. (2) In connection with the settlement agreement entered into among PG&E Corporation, the Utility, and the CPUC in 2003 to resolve the Utility’s 2001 proceeding under Chapter 11, the CPUC authorized the Utility to recover $1.2 billion of costs related to the Utility’s retained generation assets. The individual components of these regulatory assets are being amortized over the respective lives of the underlying generation facilities, consistent with the period over which the related revenues are recognized. (3 ) Includes costs of responding to catastrophic events that have been declared a disaster or state of emergency by competent federal or state authorities. As of December 31, 2021 and 2020, $49 million in COVID-19 related costs was recorded to CEMA regulatory assets. Recovery of CEMA costs is subject to CPUC review and approval. (4) Balance as of December 31, 2021 represents incremental wildfire claims and outside legal expenses related to the 2021 Dixie fire. Balance as of December 31, 2020 is comprised of incremental wildfire liability insurance premium costs for the period July 26, 2017 through December 31, 2019. Recovery of WEMA costs is subject to CPUC review and approval. (5) Includes costs associated with the implementation of regulations and requirements adopted to protect the public from potential fire hazards associated with overhead power line facilities and nearby aerial communication facilities that have not been previously authorized in another proceeding. Recovery of FHPMA costs is subject to CPUC review and approval. (6) Includes costs associated with the 2019 WMP for the period January 1, 2019 through June 4, 2019 and other incremental costs associated with fire risk mitigation. Recovery of FRMMA costs is subject to CPUC review and approval. (7) Includes costs associated with the 2019 WMP for the period June 5, 2019 through December 31, 2019 and the 2020 WMP for the period of January 1, 2020 through December 31, 2020 and the 2021 WMP for the period of January 1, 2021 through December 31, 2021. Recovery of WMPMA costs is subject to CPUC review and approval. (8) Represents cumulative differences between amounts recognized for ratemaking purposes and expense recognized in accordance with GAAP. (9) Represents excess liability insurance premium costs recorded to RTBA and adjustment mechanism for costs determined in other proceedings, as authorized in the 2020 GRC and 2019 GT&S rate cases, respectively. (10) Includes costs associated with certain wildfire mitigation activities for the period January 1, 2020 through December 31, 2021 . Noncurrent balance represents costs above 115% of adopted revenue requirements, which are subject to CPUC review and approval. (11) The GRC memorandum accounts record the difference between the gas and electric revenue requirements in effect on January 1, 2020 and through February 28, 2021 as authorized by the CPUC in December 2020. These amounts will be recovered through rates over 22 months, beginning March 1, 2021. (12) Represents costs from routine vegetation management and EVM activities previously recorded in the FRMMA/WMPMA, and tree mortality and fire risk reduction work previously recorded in CEMA for the period January 1, 2020 through December 31, 2021 . Recovery of VMBA costs above 120% of adopted revenue requirements is subject to CPUC review and approval. (13) On April 16, 2020, the CPUC passed a resolution that established the CPPMA to recover costs associated with customer protections, including higher uncollectible costs related to a moratorium on electric and gas service disconnections for residential and small business customers. The CPPMA applies only to certain residential and small business customers and was approved on July 27, 2020 with an effective date of March 4, 2020. As of December 31, 2021, the Utility had recorded an under-collection of $30 million, representing incremental bad debt expense over what was collected in rates for the period the CPPMA was in effect. The remaining $19 million is associated with program costs and higher accounts receivable financing costs. Recovery of CPPMA costs is subject to CPUC review and approval. In general, regulatory assets represent the cumulative differences between amounts recognized for ratemaking purposes and expense or accumulated other comprehensive income (loss) recognized in accordance with GAAP. Additionally, the Utility does not earn a return on regulatory assets if the related costs do not accrue interest. Accordingly, the Utility earns a return on its regulatory assets for retained generation, and regulatory assets for unamortized loss, net of gain, on reacquired debt. Regulatory Liabilities Long-term regulatory liabilities are comprised of the following: Balance at December 31, (in millions) 2021 2020 Cost of removal obligations (1) $ 7,306 $ 6,905 Recoveries in excess of AROs (2) 388 458 Public purpose programs (3) 946 948 Employee benefit plans (4) 1,229 995 Transmission tower wireless licenses (5) 446 — SFGO sale (6) 343 — Other 1,341 1,118 Total long-term regulatory liabilities $ 11,999 $ 10,424 (1) Represents the cumulative differences between the recorded costs to remove assets and amounts collected in rates for expected costs to remove assets. (2) Represents the cumulative differences between ARO expenses and amounts collected in rates. Decommissioning costs related to the Utility’s nuclear facilities are recovered through rates and are placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on these nuclear decommissioning trust investments. See Note 11 below. (3) Represents amounts received from customers designated for public purpose program costs expected to be incurred beyond the next 12 months, primarily related to energy efficiency programs. (4) Represents cumulative differences between incurred costs and amounts collected in rates for post-retirement medical, post-retirement life and long-term disability plans. (5) Represents the portion of the net proceeds received from the sale of transmission tower wireless licenses that will be returned to customers. Of the $446 million, $311 million and $135 million will be refunded to FERC and CPUC jurisdiction customers, respectively. See Note 3 above. (6) Represents the noncurrent portion of the net gain on the sale of the SFGO, which closed on September 17, 2021, that will be distributed to customers over a five-year period, beginning in 2022. Regulatory Balancing Accounts The Utility tracks (1) differences between the Utility’s authorized revenue requirement and customer billings, and (2) differences between incurred costs and customer billings. To the extent these differences are probable of recovery or refund over the next 12 months, the Utility records a current regulatory balancing account receivable or payable. Regulatory balancing accounts that the Utility expects to collect or refund over a period exceeding 12 months are recorded as other noncurrent assets – regulatory assets or noncurrent liabilities – regulatory liabilities, respectively, in the Consolidated Balance Sheets. These differences do not have an impact on net income. Balancing accounts fluctuate during the year based on seasonal electric and gas usage and the timing of when costs are incurred and customer revenues are collected. Current regulatory balancing accounts receivable and payable are comprised of the following: Receivable (in millions) 2021 2020 Gas distribution and transmission $ — $ 102 Energy procurement 310 413 Public purpose programs 321 292 Fire hazard prevention memorandum account 50 121 Fire risk mitigation memorandum account 14 33 Wildfire mitigation plan memorandum account 67 161 Wildfire mitigation balancing account 91 27 General rate case memorandum accounts 468 313 Vegetation management balancing account 127 115 Insurance premium costs 605 135 Wildfire expense memorandum account 440 — Residential uncollectibles balancing accounts 127 — Other 379 289 Total regulatory balancing accounts receivable $ 2,999 $ 2,001 Payable (in millions) 2021 2020 Electric distribution $ 121 $ 55 Electric transmission 24 267 Gas distribution and transmission 83 76 Energy procurement 211 158 Public purpose programs 259 410 Nuclear decommissioning adjustment mechanism 137 — Other 286 279 Total regulatory balancing accounts payable $ 1,121 $ 1,245 The electric distribution and utility generation accounts track the collection of revenue requirements approved in the GRC. The electric transmission accounts track recovery of costs related to the transmission of electricity approved in the FERC TO rate cases. The gas distribution and transmission accounts track the collection of revenue requirements approved in the GRC and the GT&S rate case. Energy procurement balancing accounts track recovery of costs related to the procurement of electricity, including any environmental compliance-related activities. Public purpose programs balancing accounts are primarily used to record and recover authorized revenue requirements for CPUC-mandated programs such as energy efficiency. The FHPMA tracks costs that protect the public from potential fire hazards. The FRMMA and WMPMA balances track costs that are recoverable within 12 months as requested in the 2020 WMCE application. The WMBA tracks costs associated with wildfire mitigation revenue requirement activities. The GRC memorandum accounts track the difference between the revenue requirements in effect on January 1, 2021 and the revenue requirements authorized in the final decision for the 2020 GRC. The VMBA tracks routine and EVM activities. The insurance premium costs track the current portion of incremental excess liability insurance costs recorded to RTBA and adjustment mechanism for costs determined in other proceedings, as authorized in the 2020 GRC and 2019 GT&S rate cases, respectively. In addition to insurance premium costs recorded in Regulatory balancing accounts receivable and in Long-term regulatory assets above, at December 31, 2021, there was $82 million in insurance premium costs recorded in Current regulatory assets. The WEMA balancing accounts track insurance premium costs paid by the Utility between July 26, 2017 through December 31, 2019 that are incremental to those authorized in the 2017 GRC. On October 21, 2021, the CPUC adopted a final decision approving a settlement agreement among the Utility and other active parties that authorized the Utility to recover $445.5 million over a 12-month period beginning January 1, 2022. The RUBA tracks costs a ssociated with customer protections, including higher uncollectible costs related to a moratorium on electric and gas service disconnections for residential customers. The nuclear decommissioning adjustment mechanism tracks costs related to the closure of the Diablo Canyon power plant.

DEBT

DEBT	12 Months Ended
DEBT	Dec. 31, 2021
Debt Disclosure [Abstract]
DEBT	DEBT Credit Facilities The following table summarizes PG&E Corporation’s and the Utility’s outstanding borrowings and availability under their credit facilities at December 31, 2021: (in millions) Termination Maximum Facility Limit Loans Outstanding Letters of Credit Outstanding Facility Utility revolving credit facility June 2026 $ 4,000 (1) $ 1,885 $ 692 $ 1,423 Utility term loan credit facility October 2022 (2) 1,441 (2) 1,441 (2) — — Utility receivables securitization program (3) September 2023 1,000 (4) 974 — — (4) PG&E Corporation revolving credit facility June 2024 500 — — 500 Total credit facilities $ 6,941 $ 4,300 $ 692 $ 1,923 (1) Includes a $1.5 billion letter of credit sublimit. (2 On February 8, 2022, the Utility amended the Utility Term Loan Credit Agreement to, among other things, extend the maturity date of the 18-Month Tranche Loans to January 1, 2023 for those lenders who consented to such extension; the 18-Month Tranche Loans of the non-consenting lenders in an amount equal to $142.5 million were paid in full as of February 8, 2022. (3) On October 5, 2020, the Utility entered into an accounts receivable securitization program (the “Receivables Securitization Program”), providing for the sale of a portion of the Utility's accounts receivable to the SPV, a limited liability company wholly owned by the Utility. On September 15, 2021, the Receivables Securitization Program was amended and extended to September 15, 2023. For more information, see “Variable Interest Entities” in Note 3 above. (4) The amount the Utility may borrow under the Receivables Securitization Program is limited to the lesser of the facility limit and the facility availability. The facility availability may vary based on the amount of accounts receivable that the Utility owns that are eligible for sale to the SPV and the portion of those accounts receivable that are sold to the SPV that are eligible for advances by the lenders under the Receivables Securitization Program. As of December 31, 2021, the Receivables Securitization Program had a maximum borrowing base of $974 million and was fully drawn. Utility As previously disclosed, on July 1, 2020, the Utility entered into a $3.5 billion revolving credit agreement (the “Utility Revolving Credit Agreement”) with JPMorgan Chase Bank, N.A. and Citibank, N.A. as co-administrative agents, and Citibank, N.A., as designated agent. The Utility Revolving Credit Agreement had an initial maturity date of July 1, 2023, subject to two one-year extensions at the option of the Utility. As previously disclosed, on June 22, 2021, the Utility amended the Utility Revolving Credit Agreement to, among other things, (i) increase the aggregate commitments provided by the lenders thereunder to $4.0 billion, (ii) extend the maturity date of such agreement to June 22, 2026 (subject to two one-year extensions at the option of the Utility), and (iii) provide for reduced interest rates and commitment fee rates based on the credit rating of the Utility. As previously disclosed, on July 1, 2020, the Utility entered into a $3.0 billion term loan credit agreement (the “Utility Term Loan Credit Agreement”) comprised of 364-day tranche loans in the aggregate principal amount of $1.5 billion (the “364-Day Tranche Loans”) and 18-month tranche loans in the aggregate principal amount of $1.5 billion (the “18-Month Tranche Loans”). As previously disclosed, the 364-Day Tranche Loans were paid in full on March 11, 2021. The 18-Month Tranche Loans had an initial maturity date of January 1, 2022. The Utility borrowed the entire amount of the Utility 364-Day Term Loan Facility and the Utility 18-Month Term Loan Facility on July 1, 2020. The proceeds were used to fund transactions contemplated under the Plan. On October 29, 2021 and on December 31, 2021, the Utility amended the Utility Term Loan Credit Agreement to, among other things, extend the maturity date of the 18-Month Tranche Loans to October 1, 2022. On February 8, 2022, the Utility amended the Utility Term Loan Credit Agreement to, among other things, extend the maturity date of the 18-Month Tranche Loans to January 1, 2023 for those lenders who consented to such extension; the 18-Month Tranche Loans of the non-consenting lenders in an amount equal to $142.5 million were paid in full as of February 8, 2022. To the extent that any 18-Month Tranche Loans remain outstanding on April 1, 2022, a fee will be due and owing to the lenders holding such 18-Month Tranche Loans. PG&E Corporation As previously disclosed, on July 1, 2020, PG&E Corporation entered into a $500 million revolving credit agreement (the “Corporation Revolving Credit Agreement”). The Corporation Revolving Credit Agreement had a maturity date of July 1, 2023, (subject to two one-year extensions at the option of PG&E Corporation). Any future proceeds from the loans under the Corporation Revolving Credit Agreement will be used to finance working capital needs, capital expenditures and other general corporate purposes of PG&E Corporation and its subsidiaries. As previously disclosed, on June 22, 2021, PG&E Corporation amended the Corporation Revolving Credit Agreement to, among other things, (i) extend the maturity date of such agreement to June 22, 2024 (subject to two one-year extensions at the option of PG&E Corporation) and (ii) modify both the interest rate pricing grid and commitment fee pricing grid. PG&E Corporation’s obligations under the Corporation Revolving Credit Agreement are secured by a pledge of PG&E Corporation’s ownership interest in 100% of the shares of common stock of the Utility. Intercompany Note Payable On August 11, 2021, PG&E Corporation borrowed $145 million from the Utility under an interest bearing 364-day intercompany note due August 10, 2022. The intercompany note includes usual and customary provisions for notes of this type. The interest rate on the loan is a variable rate equal to the interest rate applicable to loans under the Corporation Revolving Credit Agreement. Interest is due on the last business day of each month, commencing on August 31, 2021. The proceeds were borrowed to fund debt service obligations of PG&E Corporation. As of December 31, 2021, the intercompany note is reflected in Accounts receivable - other on the Utility’s Consolidated Balance Sheet and is eliminated upon consolidation of PG&E Corporation’s Consolidated Balance Sheet. AB 1054 AB 1054 provides that certain capital expenditures may be financed using a structure that securitizes a dedicated customer charge. On February 24, 2021, the Utility filed an application with the CPUC seeking authorization, pursuant to AB 1054, for a transaction to finance, using securitization, up to $1.19 billion of fire risk mitigation capital expenditures that have been or will be incurred by the Utility in 2020 and 2021, with the final amount to be financed based on the capital expenditures incurred by the Utility prior to the securitization transaction. On June 24, 2021, the CPUC issued a financing order authorizing the issuance of up to approximately $1.2 billion of recovery bonds to recover up to $1.19 billion of fire risk mitigation capital expenditures plus an estimated $13.3 million in related upfront financing costs. On July 6, 2021, the financing order became final and non-appealable. On November 12, 2021, PG&E Recovery Funding LLC issued approximately $860 million of senior secured recovery bonds. The recovery bonds were issued in three tranches: (1) approximately $266 million with an interest rate of 1.46% and is due July 15, 2033, (2) approximately $160 million with an interest rate of 2.28% and is due January 15, 2038, and (3) approximately $434 million with an interest rate of 2.82% and is due July 15, 2048. The net proceeds were used to fund fire risk mitigation capital expenditures that have been incurred by the Utility and incurred by PG&E Corporation on behalf of the Utility in 2020 and 2021. For more information on PG&E Recovery Fund LLC, see “Variable Interest Entities” in Note 3 above. SB 901 SB 901, signed into law on September 21, 2018, requires the CPUC to establish a CHT, directing the CPUC to limit certain disallowances in the aggregate, so that they do not exceed the maximum amount that the Utility can pay without harming customers or materially impacting its ability to provide adequate and safe service. SB 901 also authorizes the CPUC to issue a financing order that permits recovery, through the issuance of recovery bonds (also referred to as “securitization”), of wildfire-related costs found to be just and reasonable by the CPUC and, only for the 2017 Northern California wildfires, any amounts in excess of the CHT. Pursuant to SB 901 and the CPUC’s methodology adopted in the CHT OIR, on April 30, 2020, the Utility filed an application with the CPUC seeking authorization for a post-emergence transaction to finance, using securitization, $7.5 billion of 2017 wildfire claims costs and create a corresponding customer credit trust that is designed to not impact amounts billed to customers, with the proceeds of the securitization used to pay or reimburse the Utility for the payment of wildfire claims costs associated with the 2017 Northern California wildfires. In connection with the proposed transaction, the Utility would retire $6.0 billion of Utility debt. On April 23, 2021, the CPUC issued a decision finding that $7.5 billion of the Utility’s 2017 catastrophic wildfire costs and expenses are stress test costs that may be financed through the issuance of recovery bonds pursuant to Public Utilities Code sections 850 et seq. The decision is being challenged by TURN. Short-Term Debt Issuance On November 15, 2021, the Utility completed the sale of $300 million aggregate principal amount of Floating Rate First Mortgage Bonds due November 14, 2022. The proceeds, along with the long-term debt proceeds from the First Mortgage Bonds also issued on November 15, 2021, were used for the repayment of the $1.45 billion aggregate principal amount of the Utility’s Floating Rate First Mortgage Bonds due November 15, 2021. Long-Term Debt Issuances and Redemptions Utility In March 2021, the Utility issued (i) $1.5 billion aggregate principal amount of 1.367% First Mortgage Bonds due March 10, 2023, (ii) $450 million aggregate principal amount of 3.25% First Mortgage Bonds due June 1, 2031, and (iii) $450 million aggregate principal amount of 4.20% First Mortgage Bonds due June 1, 2041. The proceeds were used for (i) the prepayment of all of the $1.5 billion 364-day term loan facility (maturing June 30, 2021) outstanding under the Utility’s Term Loan Credit Agreement, (ii) the repayment of all of the borrowings outstanding under the Utility’s revolving credit facility pursuant to the Utility Revolving Credit Agreement and (iii) general corporate purposes. In June 2021, the Utility issued $800 million aggregate principal amount of 3.0% First Mortgage Bonds due June 15, 2028. The proceeds were used for general corporate purposes, including the repayment of borrowings under the Utility’s revolving credit facility pursuant to the Utility Revolving Credit Agreement. On November 15, 2021, the Utility completed the sale of (i) $900 million aggregate principal amount of 1.70% First Mortgage Bonds due November 15, 2023 and (ii) an additional $550 million aggregate principal amount of 3.25% First Mortgage Bonds due June 1, 2031 (the “2031 Bonds”). The 2031 Bonds are part of the same series of debt securities issued by the Utility in March 2021. The proceeds were used for the repayment of the $1.45 billion aggregate principal amount of the Utility’s Floating Rate First Mortgage Bonds due November 15, 2021. The Utility used the remaining net proceeds for general corporate purposes, including the repayment of approximately $300 million of borrowings outstanding under the Utility’s revolving credit facility pursuant to the Utility Revolving Credit Agreement. The following table summarizes PG&E Corporation’s and the Utility’s long-term debt: Balance at (in millions) Contractual Interest Rates December 31, 2021 December 31, 2020 PG&E Corporation Term Loan - Stated Maturity: 2025 variable rate (1) $ 2,709 $ 2,709 Senior Secured Notes due 2028 5.00% 1,000 1,000 Senior Secured Notes due 2030 5.25% 1,000 1,000 Less: current portion, net of debt issuance costs (26) — Unamortized discount, net of premium and debt issuance costs (90) (85) Total PG&E Corporation Long-Term Debt 4,593 4,624 Utility First Mortgage Bonds - Stated Maturity: 2022 variable rate (2) 500 500 2022 1.75% 2,500 2,500 2023 1.37% - 4.25% 3,575 1,175 2024 3.40% - 3.75% 800 800 2025 3.45% - 3.50% 1,475 1,475 2026 2.95% - 3.15% 2,551 2,551 2027 2.10% - 3.30% 2,550 2,550 2028 3.00% - 4.65% 1,975 1,175 2030 4.55% 3,100 3,100 2031 2.50% - 3.25% 3,000 2,000 2040 3.30% - 4.50% 2,951 2,951 2041 4.20% - 4.50% 700 250 2042 3.75% - 4.45% 750 750 2043 4.60% 375 375 2044 4.75% 675 675 2045 4.30% 600 600 2046 4.00% - 4.25% 1,050 1,050 2047 3.95% 850 850 2050 3.50% - 4.95% 5,025 5,025 Less: current portion, net of debt issuance costs (2,996) — Unamortized discount, net of premium and debt issuance costs (190) (182) Total Utility First Mortgage Bonds 31,816 30,170 Recovery Bonds 1.46% - 2.82% 860 — Less: current portion (18) — Credit Facilities Receivables securitization program - Stated Maturity: 2023 variable rate (3) 974 1,000 18-month Term Loan - Stated Maturity: 2022 variable rate (4) 1,441 1,500 Less: current portion (1,441) — Unamortized discount, net of premium and debt issuance costs — (6) Total Utility Long-Term Debt 33,632 32,664 Total PG&E Corporation Consolidated Long-Term Debt $ 38,225 $ 37,288 (1) At December 31, 2021 and 2020, the contractual LIBOR-based interest rate on the term loan was 3.50% and 5.50%, respectively. (2) At December 31, 2021 and 2020, the contractual LIBOR-based interest rate on $500 million of the first mortgage bonds was 1.69% and 1.70%, respectively. (3) At December 31, 2021 and 2020, the contractual LIBOR-based interest rate on the receivables securitization program was 1.30% and 1.57%, respectively. (4) At December 31, 2021 and 2020, the contractual LIBOR-based interest rate on the term loan was 2.38% and 2.44%, respectively. Contractual Repayment Schedule PG&E Corporation’s and the Utility’s combined stated long-term debt principal repayment amounts at December 31, 2021 are reflected in the table below: (in millions, except interest rates) 2022 2023 2024 2025 2026 Thereafter Total PG&E Corporation Average fixed interest rate — % — % — % — % — % 5.13 % 5.13 % Fixed rate obligations $ — $ — $ — $ — $ — $ 2,000 $ 2,000 Variable interest rate as of December 31, 2021 3.50 % 3.50 % 3.50 % 3.50 % — % — % 3.50 % Variable rate obligations $ 28 $ 28 $ 28 $ 2,625 $ — $ — $ 2,709 Utility Average fixed interest rate 1.75 % 2.26 % 3.60 % 3.47 % 3.10 % 3.90 % 3.49 % Fixed rate obligations $ 2,500 $ 3,575 $ 800 $ 1,475 $ 2,551 $ 23,601 $ 34,502 Variable interest rate as of December 31, 2021 2.20 % various (1) — % — % — % — % various (1) Variable rate obligations $ 1,941 $ 974 $ — $ — $ — $ — $ 2,915 Total consolidated debt $ 4,469 $ 4,577 $ 828 $ 4,100 $ 2,551 $ 25,601 $ 42,126 (1) At December 31, 2021, the average interest rates for the Receivables Securitization Program, the first mortgage bonds due 2022 and the 18-month term loan were 1.30%, 1.69% and 2.38% respectively.

COMMON STOCK AND SHARE-BASED CO

COMMON STOCK AND SHARE-BASED COMPENSATION	12 Months Ended
COMMON STOCK AND SHARE-BASED COMPENSATION	Dec. 31, 2021
Common Stock And Share-Based Compensation [Abstract]
COMMON STOCK AND SHARE-BASED COMPENSATION	COMMON STOCK AND SHARE-BASED COMPENSATION PG&E Corporation had 1,985,400,540 shares of common stock outstanding at December 31, 2021, which excludes 477,743,590 shares of common stock issued to ShareCo. PG&E Corporation held all of the Utility’s outstanding common stock at December 31, 2021. Equity Offerings During 2020, PG&E Corporation issued approximately 16 million PG&E Corporation equity units. The equity units represent the right of the unitholders to receive, on the settlement date, between 138 million and 168 million shares of PG&E Corporation common stock. The common stock received will be based on the value of PG&E Corporation common stock over a measurement period specified in the equity units purchase contracts and subject to certain adjustments as provided therein. The settlement date of the equity unit purchase contracts is August 16, 2023, subject to acceleration or postponement as provided in the purchase contracts. At the Market Equity Distribution Program On April 30, 2021, PG&E Corporation entered into an Equity Distribution Agreement (“Equity Distribution Agreement”) with Barclays Capital Inc., BofA Securities, Inc., Credit Suisse Securities (USA) LLC and Wells Fargo Securities, LLC, as sales agents and as forward sellers (in such capacities as applicable, the “Agents” and the “Forward Sellers,” respectively), and Barclays Bank PLC, Bank of America, N.A., Credit Suisse Capital LLC and Wells Fargo Bank, National Association, as forward purchasers (the “Forward Purchasers”), establishing an at the market equity distribution program, pursuant to which PG&E Corporation, through the Agents, may offer and sell from time to time shares of PG&E Corporation’s common stock having an aggregate gross sales price of up to $400 million. PG&E Corporation has no obligation to offer or sell any of its common stock under the Equity Distribution Agreement and may at any time suspend offers under the Equity Distribution Agreement. The Equity Distribution Agreement provides that, in addition to the issuance and sale of shares of common stock by PG&E Corporation to or through the Agents, PG&E Corporation may enter into forward sale agreements (collectively, the “Forward Sale Agreements”) pursuant to which the relevant Forward Purchaser will borrow shares from third parties and, through its affiliated Forward Seller, offer a number of shares of common stock equal to the number of shares of common stock underlying the particular Forward Sale Agreement. During the year ended December 31, 2021, PG&E Corporation did not sell any shares pursuant to the Equity Distribution Agreement or any Forward Sale Agreement. As of December 31, 2021, there was $400 million available under PG&E Corporation’s at the market equity distribution program for future offerings. Ownership Restrictions in PG&E Corporation’s Amended Articles Under Section 382 of the Internal Revenue Code, if a corporation (or a consolidated group) undergoes an “ownership change,” net operating loss carryforwards and other tax attributes may be subject to certain limitations (which could limit PG&E Corporation or the Utility’s ability to use these DTAs to offset taxable income). In general, an ownership change occurs if the aggregate stock ownership of certain shareholders (generally five percent shareholders, applying certain look-through and aggregation rules) increases by more than 50% over such shareholders’ lowest percentage ownership during the testing period (generally three years). The Amended Articles limit Transfers (as defined in the Amended Articles) that increase a person’s or entity’s (including certain groups of persons) ownership of PG&E Corporation’s equity securities to 4.75% or more prior to the Restriction Release Date (as defined in the Amended Articles) without approval by the Board of Directors of PG&E Corporation. On July 8, 2021, PG&E Corporation, the Utility, ShareCo and the Fire Victim Trust entered into an agreement (the “Share Exchange and Tax Matters Agreement”), pursuant to which PG&E Corporation and the Utility made a “grantor trust” election for the Fire Victim Trust effective retroactively to the inception of the Fire Victim Trust. As a result of the grantor trust election, shares of PG&E Corporation common stock owned by the Fire Victim Trust are treated as held by the Utility and, in turn attributed to PG&E Corporation for income tax purposes. Consequently, any shares owned by the Fire Victim Trust, along with any shares owned by the Utility directly, are effectively excluded from the total number of outstanding equity securities when calculating a person’s Percentage Stock Ownership (as defined in the Amended Articles) for purposes of the 4.75% ownership limitation in the Amended Articles. Shares owned by ShareCo are also effectively excluded because ShareCo is a disregarded entity for income tax purposes. For example, although PG&E Corporation had 2,463,891,104 shares outstanding as of February 4, 2022, only 1,548,403,924 shares (that is, the number of outstanding shares of common stock less the number of shares held by the Fire Victim Trust, the Utility and ShareCo) count as outstanding for purposes of the ownership restrictions in the Amended Articles. As such, based on the total number of outstanding equity securities and assuming the Fire Victim Trust has not sold any shares of PG&E Corporation common stock, a person’s effective Percentage Stock Ownership limitation for purposes of the Amended Articles as of February 4, 2022 was 2.98% of the outstanding shares. As of December 31, 2021, to the knowledge of PG&E Corporation, the Fire Victim Trust had not sold any shares of PG&E Corporation common stock. On January 31, 2022, the Fire Victim Trust initiated an exchange of 40,000,000 Plan Shares for an equal number of New Shares in the manner contemplated by the Share Exchange and Tax Matters Agreement and announced that it had entered into a transaction for the sale of these shares. As of the date of this report, it is more likely than not that PG&E Corporation has not undergone an ownership change and consequently, its net operating loss carryforwards and other tax attributes are not limited by Section 382 of the Internal Revenue Code. Share Exchange and Tax Matters Agreement In accordance with the Share Exchange and Tax Matters Agreement, the grantor trust election has been filed. With the grantor trust election, the Utility’s tax deductions occur as and when the Fire Victim Trust pays the fire victims rather than when the Utility transferred cash and other property (including PG&E Corporation common stock) to the Fire Victim Trust. For PG&E Corporation common stock transferred to the Fire Victim Trust, the amount of the tax deduction will be impacted by the price at which the Fire Victim Trust sells the shares, rather than the price at the time such shares were transferred to the Fire Victim Trust. Under the Share Exchange and Tax Matters Agreement, the parties agreed to exchange the 477,743,590 shares of PG&E Corporation common stock issued to the Fire Victim Trust pursuant to the Plan (the “Plan Shares”) for an equal number of newly-issued shares of PG&E Corporation common stock (the “New Shares”). Accordingly, on July 9, 2021, PG&E Corporation issued 477,743,590 New Shares to ShareCo, which has the sole purpose of holding the New Shares in a designated brokerage account to facilitate the exchange process. When the Fire Victim Trust desires to sell any or all of its Plan Shares, the Fire Victim Trust may exchange any number of Plan Shares for a corresponding number of New Shares on a share-for-share basis (without any further consideration payable by either party) and thereafter promptly dispose of the New Shares in one or more transactions with one or more third parties. In the event that the Fire Victim Trust is unable to timely dispose of New Shares under certain circumstances (such shares, the “Nonconforming New Shares”), PG&E Corporation has authorized up to 250,000,000 additional shares of PG&E Corporation common stock, which may be transferred by ShareCo to the Fire Victim Trust on behalf of the Utility, in exchange for the Nonconforming New Shares, following the same procedures as for an exchange of Plan Shares for New Shares. The Plan Shares and any Non-Conforming New Shares exchanged will be held thereafter by the Utility. In the event that the Fire Victim Trust disposes of any share of PG&E Corporation’s common stock subject to the Share Exchange and Tax Matters Agreement without complying with the terms of the agreement, the Fire Victim Trust may be required to make a payment to the Utility designed to compensate the Utility for adverse tax consequences arising from nonconforming sale transactions. Upon PG&E Corporation’s issuance of the New Shares to ShareCo, PG&E Corporation’s common stock increased by $4.85 billion, the fair value of the shares on July 9, 2021. The increase to common stock is fully offset by the fair value of treasury stock recorded. The issuance of the New Shares did not have an impact on the total number of outstanding common shares as the New Shares are currently held by ShareCo and as such, there was no impact on basic or diluted EPS for the year ended December 31, 2021. When the Fire Victim Trust notifies the Utility that it intends to sell shares, ShareCo (on behalf of the Utility) will transfer the New Shares to the Fire Victim Trust, and the Fire Victim Trust will transfer the Plan Shares to the Utility. The Utility has no plan or intention to dispose of the Plan Shares at any time. As shares are exchanged with the Fire Victim Trust, the Utility will record the cost of shares and PG&E Corporation’s investment under additional paid in capital and PG&E Corporation’s common stock and treasury stock will decrease by the fair value per share established on July 9, 2021. As of December 31, 2021, none of the 250,000,000 reserved shares had been issued. Dividends On December 20, 2017, the Boards of Directors of PG&E Corporation and the Utility suspended quarterly cash dividends on both PG&E Corporation’s and the Utility’s common stock, beginning the fourth quarter of 2017, as well as the Utility’s preferred stock, beginning the three-month period ending January 31, 2018. On March 20, 2020, PG&E Corporation and the Utility filed a Case Resolution Contingency Process Motion with the Bankruptcy Court that includes a dividend restriction for PG&E Corporation. According to the dividend restriction, PG&E Corporation “will not pay common dividends until it has recognized $6.2 billion in non-GAAP core earnings following the Effective Date” of the Plan. The Bankruptcy Court entered the order approving the motion on April 9, 2020. In addition, the Corporation Revolving Credit Agreement requires that PG&E Corporation (1) maintain a ratio of total consolidated debt to consolidated capitalization of no greater than 70% as of the end of each fiscal quarter and (2) if revolving loans are outstanding as of the end of a fiscal quarter, a ratio of adjusted cash to fixed charges, as of the end of such fiscal quarter, of at least 150% prior to the date that PG&E Corporation first declares a cash dividend on its common stock and at least 100% thereafter. Under the Utility’s Articles of Incorporation, the Utility cannot pay common stock dividends unless all cumulative preferred dividends on the Utility’s preferred stock have been paid. As of January 31, 2022, there were $59.1 million of such cumulative and unpaid dividends on the Utility’s preferred stock. Additionally, the CPUC requires the Utility to maintain a capital structure composed of at least 52% equity on average. On May 28, 2020, the CPUC approved a final decision in the Chapter 11 Proceedings OII, which, among other things, grants the Utility a temporary, five Subject to the foregoing restrictions, any decision to declare and pay dividends in the future will be made at the discretion of the Boards of Directors and will depend on, among other things, results of operations, financial condition, cash requirements, contractual restrictions and other factors that the Boards of Directors may deem relevant. On February 8, 2022, the Board of Directors of the Utility authorized the payment of all cumulative and unpaid dividends on the Utility’s preferred stock as of January 31, 2022 totaling $59.1 million, payable on May 13, 2022, to holders of record on April 29, 2022 and declared a dividend on the Utility’s preferred stock totaling $3.5 million that will be accrued during the three-month period ending April 30, 2022, payable on May 15, 2022, to holders of record on April 29, 2022. It is uncertain when PG&E Corporation and the Utility will commence the payment of dividends on their common stock. Long-Term Incentive Plan The LTIP permits various forms of share-based incentive awards, including stock options, restricted stock units, performance shares, and other share-based awards, to eligible employees of PG&E Corporation and its subsidiaries. Non-employee directors of PG&E Corporation are also eligible to receive certain share-based awards. A maximum of 91 million shares of PG&E Corporation common stock (subject to certain adjustments) has been reserved for issuance under the LTIP, of which 58,552,722 shares were available for future awards at December 31, 2021. The following table provides a summary of total share-based compensation expense recognized by PG&E Corporation for share-based incentive awards for 2021: (in millions) 2021 2020 2019 Stock Options $ — $ 3 $ 7 Restricted stock units 35 15 21 Performance shares 21 17 22 Total compensation expense (pre-tax) $ 56 $ 35 $ 50 Total compensation expense (after-tax) $ 40 $ 25 $ 35 Share-based compensation costs are generally not capitalized. There was no material difference between PG&E Corporation and the Utility for the information disclosed above. Stock Options The exercise price of stock options granted under the LTIP and all other outstanding stock options is equal to the market price of PG&E Corporation’s common stock on the date of grant. Stock options generally have a 10-year term and vest over three years of continuous service, subject to accelerated vesting in certain circumstances. As of December 31, 2021, there were no unrecognized compensation costs related to nonvested stock options for PG&E Corporation. The fair value of each stock option on the date of grant is estimated using the Black-Scholes valuation method. No stock options were granted in 2021 and 2020. Expected volatilities are based on historical volatility of PG&E Corporation’s common stock. The expected dividend payment is the dividend yield at the date of grant. The risk-free interest rate for periods within the contractual term of the stock option is based on the U.S. Treasury rates in effect at the date of grant. The expected life of stock options is derived from historical data that estimates stock option exercises and employee departure behavior. There was no tax benefit recognized from stock options for the year ended December 31, 2021. The following table summarizes stock option activity for PG&E Corporation and the Utility for 2021: Number of Weighted Average Grant- Weighted Average Remaining Contractual Term Aggregate Intrinsic Value Outstanding at January 1 2,221,247 $ 7.45 $ — Granted (1) — — — Exercised — — — Forfeited or expired (25,413) 10.23 — Outstanding at December 31 2,195,834 7.42 4.33 — Vested or expected to vest at December 31 2,195,834 7.42 4.33 — Exercisable at December 31 2,195,834 $ 7.42 4.33 $ — (1) Represents additional payout of existing stock option grants. Restricted Stock Units Restricted stock units granted after 2014 generally vest equally over three years. Vested restricted stock units are settled in shares of PG&E Corporation common stock accompanied by cash payments to settle any dividend equivalents associated with the vested restricted stock units. Compensation expense is generally recognized ratably over the vesting period based on grant-date fair value. The weighted average grant-date fair value for restricted stock units granted during 2021, 2020, and 2019 was $11.01, $9.25, and $18.57, respectively. The total fair value of restricted stock units that vested during 2021, 2020, and 2019 was $19 million, $31 million, and $42 million, respectively. The tax detriment from restricted stock units that vested in 2021 was $11 million. In general, forfeitures are recorded ratably over the vesting period, using historical averages and adjusted to actuals when vesting occurs. As of December 31, 2021, $81 million of total unrecognized compensation costs related to nonvested restricted stock units was expected to be recognized over the remaining weighted average period of 2.19 years. The following table summarizes restricted stock unit activity for 2021: Number of Weighted Average Grant- Nonvested at January 1 890,353 $ 23.05 Granted 10,352,117 11.01 Vested (743,672) 25.20 Forfeited (408,423) 11.67 Nonvested at December 31 10,090,375 $ 11.00 Performance Shares Performance shares generally will vest three three Compensation expense attributable to performance shares is generally recognized ratably over the applicable three The following table summarizes activity for performance shares in 2021: Number of Weighted Average Grant- Nonvested at January 1 7,288,782 $ 9.16 Granted 2,714,645 11.83 Vested — — Forfeited (1) (1,436,418) 11.35 Nonvested at December 31 8,567,009 $ 9.64 (1) Includes performance shares that expired with zero value as performance targets were not met.

PREFERRED STOCK

PREFERRED STOCK	12 Months Ended
PREFERRED STOCK	Dec. 31, 2021
Preferred Stock [Abstract]
PREFERRED STOCK	PREFERRED STOCK PG&E Corporation has authorized 400 million shares of preferred stock, none of which is outstanding. The Utility has authorized 75 million shares of first preferred stock, with a par value of $25 per share, and 10 million shares of $100 first preferred stock, with a par value of $100 per share. At December 31, 2021 and 2020, the Utility’s preferred stock outstanding included $145 million of shares with interest rates between 5% and 6% designated as nonredeemable preferred stock and $113 million of shares with interest rates between 4.36% and 5% that are redeemable between $25.75 and $27.25 per share, respectively. The Utility’s preferred stock outstanding are not subject to mandatory redemption. No shares of $100 first preferred stock are outstanding. On December 31, 2021, annual dividends on the Utility’s nonredeemable preferred stock ranged from $1.25 to $1.50 per share. The Utility’s redeemable preferred stock is subject to redemption at the Utility’s option, in whole or in part, if the Utility pays the specified redemption price plus accumulated and unpaid dividends through the redemption date. At December 31, 2021, annual dividends on redeemable preferred stock ranged from $1.09 to $1.25 per share. Dividends on all Utility preferred stock are cumulative. All shares of preferred stock have voting rights and an equal preference in dividend and liquidation rights. Upon liquidation or dissolution of the Utility, holders of preferred stock would be entitled to the par value of such shares plus all accumulated and unpaid dividends, as specified for the class and series. On February 8, 2022, the Board of Directors of the Utility authorized the payment of all cumulative and unpaid dividends on the Utility’s preferred stock as of January 31, 2022 totaling $59.1 million, payable on May 13, 2022, to holders of record on April 29, 2022 and declared a dividend on the Utility’s preferred stock totaling $3.5 million that will be accrued during the three-month period ending April 30, 2022, payable on May 15, 2022, to holders of record on April 29, 2022.

EARNINGS PER SHARE

EARNINGS PER SHARE	12 Months Ended
EARNINGS PER SHARE	Dec. 31, 2021
Earnings Per Share [Abstract]
EARNINGS PER SHARE	EARNINGS PER SHARE PG&E Corporation’s basic EPS is calculated by dividing the income (loss) available for common shareholders by the weighted average number of common shares outstanding. PG&E Corporation applies the treasury stock method of reflecting the dilutive effect of outstanding share-based compensation in the calculation of diluted EPS. The following is a reconciliation of PG&E Corporation’s income (loss) available for common shareholders and weighted average common shares outstanding for calculating diluted EPS for 2021, 2020, and 2019. Year Ended December 31, (in millions, except per share amounts) 2021 2020 2019 Loss attributable to common shareholders $ (102) $ (1,318) $ (7,656) Weighted average common shares outstanding, basic 1,985 1,257 528 Add incremental shares from assumed conversions: Employee share-based compensation — — — Equity Units — — — Weighted average common share outstanding, diluted 1,985 1,257 528 Total Loss per common share, diluted $ (0.05) $ (1.05) $ (14.50) For each of the periods presented above, the calculation of outstanding common shares on a diluted basis excluded an insignificant amount of options and securities that were antidilutive.

INCOME TAXES

INCOME TAXES	12 Months Ended
INCOME TAXES	Dec. 31, 2021
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES PG&E Corporation and the Utility use the asset and liability method of accounting for income taxes. The income tax provision includes current and deferred income taxes resulting from operations during the year. PG&E Corporation and the Utility estimate current period tax expense in addition to calculating DTAs and liabilities. DTAs and liabilities result from temporary tax and accounting timing differences, such as those arising from depreciation expense. PG&E Corporation and the Utility recognize a tax benefit if it is more likely than not that a tax position taken or expected to be taken in a tax return will be sustained upon examination by taxing authorities based on the technical merits of the position. The tax benefit recognized in the financial statements is measured based on the largest amount of benefit that is greater than 50% likely of being realized upon settlement. As such, the difference between a tax position taken or expected to be taken in a tax return in future periods and the benefit recognized and measured pursuant to this guidance in the financial statements represents an unrecognized tax benefit. Investment tax credits are deferred and amortized to income over time. PG&E Corporation amortizes its investment tax credits over the projected investment recovery period. The Utility amortizes its investment tax credits over the life of the related property in accordance with regulatory treatment. PG&E Corporation files a consolidated U.S. federal income tax return that includes the Utility and domestic subsidiaries in which its ownership is 80% or more. PG&E Corporation files a combined state income tax return in California. PG&E Corporation and the Utility are parties to a tax-sharing agreement under which the Utility determines its income tax provision (benefit) on a stand-alone basis. The significant components of income tax provision (benefit) by taxing jurisdiction were as follows: PG&E Corporation Utility Year Ended December 31, (in millions) 2021 2020 2019 2021 2020 2019 Current: Federal $ — $ (26) $ 1 $ — $ (26) $ 4 State 1 (34) 101 — (34) 94 Deferred: Federal 543 258 (2,361) 588 290 (2,363) State 296 171 (1,136) 316 185 (1,137) Tax credits (4) (7) (5) (4) (7) (5) Income tax provision (benefit) $ 836 $ 362 $ (3,400) $ 900 $ 408 $ (3,407) The following tables describe net deferred income tax assets and liabilities: PG&E Corporation Utility Year Ended December 31, (in millions) 2021 2020 2021 2020 Deferred income tax assets: Tax carryforwards $ 5,628 $ 7,641 $ 5,425 $ 7,529 Compensation 185 187 108 109 Wildfire-related claims (1) 1,723 544 1,723 544 Operating lease liability 346 489 346 488 Transmission tower wireless licenses 266 — 266 — Other (2) 278 212 293 219 Total deferred income tax assets $ 8,426 $ 9,073 $ 8,161 $ 8,889 Deferred income tax liabilities: Property related basis differences 8,847 8,311 8,835 8,300 Regulatory balancing accounts 1,193 763 1,193 763 Debt financing costs 501 526 501 526 Operating lease right of use asset 346 489 346 488 Income tax regulatory asset (3) 517 254 517 254 Other (4) 199 128 178 128 Total deferred income tax liabilities $ 11,603 $ 10,471 $ 11,570 $ 10,459 Total net deferred income tax liabilities $ 3,177 $ 1,398 $ 3,409 $ 1,570 (1) Amounts primarily relate to wildfire-related claims, net of estimated insurance recoveries, and legal and other costs related to various wildfires that have occurred in PG&E Corporation’s and the Utility’s service territory over the past several years. (2) Amounts include benefits, environmental reserve, and customer advances for construction. (3) Represents the tax gross up portion of the deferred income tax for the cumulative differences between amounts recognized for ratemaking purposes and amounts recognized for tax, including the impact of changes in net deferred taxes associated with a lower federal income tax rate as a result of the Tax Act. (4) Amount primarily includes an environmental reserve. The following table reconciles income tax expense at the federal statutory rate to the income tax provision: PG&E Corporation Utility Year Ended December 31, 2021 2020 2019 2021 2020 2019 Federal statutory income tax rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) in income tax rate resulting from: State income tax (net of federal benefit) (1) 31.3 (15.3) 7.5 24.1 19.1 7.5 Effect of regulatory treatment of fixed asset differences (2) (71.5) 39.0 2.8 (51.6) (44.9) 2.8 Tax credits (1.7) 1.5 0.1 (1.2) (1.7) 0.1 Fire Victim Trust (3) 127.3 (44.9) — 91.9 51.7 — Bankruptcy and emergence — (37.6) — — 2.4 — Other, net (4) 5.3 (2.1) (0.6) 2.6 2.2 (0.5) Effective tax rate 111.7 % (38.4) % 30.8 % 86.8 % 49.8 % 30.9 % (1) Includes the effect of state flow-through ratemaking treatment. (2) Includes the effect of federal flow-through ratemaking treatment for certain property-related costs. For these temporary tax differences, PG&E Corporation and the Utility recognize the deferred tax impact in the current period and record offsetting regulatory assets and liabilities. Therefore, PG&E Corporation’s and the Utility’s effective tax rates are impacted as these differences arise and reverse. PG&E Corporation and the Utility recognize such differences as regulatory assets or liabilities as it is probable that these amounts will be recovered from or returned to customers in future rates. In 2021, 2020, and 2019, the amounts also reflect the impact of the amortization of excess deferred tax benefits to be refunded to customers as a result of the Tax Act passed in December 2017. (3) The Utility includes an adjustment for a DTA write-off associated with the grantor trust election for the Fire Victim Trust in 2021 and an adjustment for the DTA write-off for difference between the liability recorded related to the TCC RSA and the ultimate value of PG&E Corporation stock contributed to the Fire Victim Trust in 2020. PG&E Corporation includes the same adjustment as the Utility in 2021 and 2020 as well as a permanent non-deductible equity backstop premium expense in 2020. This combined with a pre-tax loss and a pre-tax income for PG&E Corporation and the Utility, respectively in 2020, accounts for the remaining difference. (4) These amounts primarily represent the impact of tax audit settlements and non-tax deductible penalty costs in 2021 and 2020. Unrecognized Tax Benefits The following table reconciles the changes in unrecognized tax benefits: PG&E Corporation Utility (in millions) 2021 2020 2019 2021 2020 2019 Balance at beginning of year $ 437 $ 420 $ 377 $ 437 $ 420 $ 377 Reductions for tax position taken during a prior year (23) (43) (1) (23) (43) (1) Additions for tax position taken during the current year 85 60 44 85 60 44 Settlements (1) — — (1) — — Balance at end of year $ 498 $ 437 $ 420 $ 498 $ 437 $ 420 The component of unrecognized tax benefits that, if recognized, would affect the effective tax rate at December 31, 2021 for PG&E Corporation and the Utility was $30 million. PG&E Corporation’s and the Utility’s unrecognized tax benefits are not likely to change significantly within the next 12 months. Interest income, interest expense and penalties associated with income taxes are reflected in income tax expense on the Consolidated Statements of Income. For the years ended December 31, 2021, 2020, and 2019, these amounts were immaterial. Tax Settlements PG&E Corporation’s tax returns have been accepted through 2015 for federal income tax purposes, except for a few matters, the most significant of which relate to deductible repair costs for gas transmission and distribution lines of business and tax deductions claimed for regulatory fines and fees assessed as part of the penalty decision issued in 2015 for the San Bruno natural gas explosion in September of 2010. PG&E Corporation’s tax returns have been accepted through 2014 for California income tax purposes. Tax years 2015 and thereafter remain subject to examination by the State of California. Carryforwards The following table describes PG&E Corporation’s operating loss and tax credit carryforward balances: (in millions) December 31, 2021 Expiration Federal: Net operating loss carryforward - Pre-2018 $ 3,600 2031 - 2036 Net operating loss carryforward - Post-2017 17,467 N/A Tax credit carryforward 144 2029 - 2041 State: Net operating loss carryforward $ 18,853 2039 - 2041 Tax credit carryforward 122 Various PG&E Corporation does not believe that the Chapter 11 Cases resulted in loss of or limitation on the utilization of any of the tax carryforwards. PG&E Corporation will continue to monitor the status of tax carryforwards. Other Tax Matters PG&E Corporation’s and the Utility’s unrecognized tax benefits are not likely to change significantly within the next 12 months. At December 31, 2021, it is reasonably possible that within the next 12 months, unrecognized tax benefits will decrease. The amount is not expected to be material. As of the date of this report, it is more likely than not that PG&E Corporation has not undergone an ownership change, and consequently, its net operating loss carryforwards and other tax attributes are not limited by Section 382 of the Internal Revenue Code. In March 2020, Congress passed, and the President signed into law the Coronavirus Aid, Relief and Economic Security (“CARES”) Act. Under the CARES Act, PG&E Corporation and the Utility have deferred the payment of 2020 payroll taxes for the remainder of the year to 2021 and 2022. Half of the payment was paid in 2021. During June 2020, the State of California enacted AB 85, which increases taxes on corporations over a three-year period beginning in 2020 by suspension of the net operating loss deduction and a limit of $5 million per year on business tax credits. PG&E Corporation and the Utility do not anticipate any material impacts to PG&E Corporation’s Consolidated Financial Statements due to this legislation.

DERIVATIVES

DERIVATIVES	12 Months Ended
DERIVATIVES	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVES	DERIVATIVES Use of Derivative Instruments The Utility is exposed to commodity price risk as a result of its electricity and natural gas procurement activities. Procurement costs are recovered through rates. The Utility uses both derivative and non-derivative contracts to manage volatility in customer rates due to fluctuating commodity prices. Derivatives include contracts, such as power purchase agreements, forwards, futures, swaps, options, and CRRs that are traded either on an exchange or over-the-counter. Derivatives are presented in the Utility’s Consolidated Balance Sheets and recorded at fair value and on a net basis in accordance with master netting arrangements for each counterparty. The fair value of derivative instruments is further offset by cash collateral paid or received where the right of offset and the intention to offset exist. Price risk management activities that meet the definition of derivatives are recorded at fair value on the Consolidated Balance Sheets. These instruments are not held for speculative purposes and are subject to certain regulatory requirements. The Utility expects to fully recover through rates all costs related to derivatives under the applicable ratemaking mechanism in place as long as the Utility’s price risk management activities are carried out in accordance with CPUC directives. Therefore, all unrealized gains and losses associated with the change in fair value of these derivatives are deferred and recorded within the Utility’s regulatory assets and liabilities on the Consolidated Balance Sheets. Net realized gains or losses on commodity derivatives are recorded in the cost of electricity or the cost of natural gas with corresponding increases or decreases to regulatory balancing accounts for recovery from or refund to customers. The Utility elects the normal purchase and sale exception for eligible derivatives. Eligible derivatives are those that require physical delivery in quantities that are expected to be used by the Utility over a reasonable period in the normal course of business, and do not contain pricing provisions unrelated to the commodity delivered. These items are not reflected in the Consolidated Balance Sheets at fair value. Volume of Derivative Activity The volumes of the Utility’s outstanding derivatives were as follows: Contract Volume At December 31, Underlying Product Instruments 2021 2020 Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 173,361,635 146,642,863 Options 14,420,000 14,140,000 Electricity (Megawatt-hours) Forwards, Futures and Swaps 10,283,639 9,435,830 Options 288,000 — Congestion Revenue Rights (3) 239,857,610 266,091,470 (1) Amounts shown are for the combined positions of the electric fuels and core gas supply portfolios. (2) Million British Thermal Units. (3) CRRs are financial instruments that enable the holders to manage variability in electric energy congestion charges due to transmission grid limitations. Presentation of Derivative Instruments in the Financial Statements At December 31, 2021, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 58 $ (9) $ 152 $ 201 Other noncurrent assets – other 169 — — 169 Current liabilities – other (53) 9 18 (26) Noncurrent liabilities – other (216) — — (216) Total commodity risk $ (42) $ — $ 170 $ 128 At December 31, 2020, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 33 $ — $ 115 $ 148 Other noncurrent assets – other 136 — — 136 Current liabilities – other (38) — 15 (23) Noncurrent liabilities – other (204) — 10 (194) Total commodity risk $ (73) $ — $ 140 $ 67 Cash inflows and outflows associated with derivatives are included in operating cash flows on the Utility’s Consolidated Statements of Cash Flows.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
FAIR VALUE MEASUREMENTS	Dec. 31, 2021
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	FAIR VALUE MEASUREMENTS PG&E Corporation and the Utility measure their cash equivalents, trust assets, and price risk management instruments at fair value. A three-tier fair value hierarchy is established that prioritizes the inputs to valuation methodologies used to measure fair value: • Level 1 – Observable inputs that reflect quoted prices (unadjusted) for identical assets or liabilities in active markets. • Level 2 – Other inputs that are directly or indirectly observable in the marketplace. • Level 3 – Unobservable inputs which are supported by little or no market activities. The fair value hierarchy requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. Assets and liabilities measured at fair value on a recurring basis for PG&E Corporation and the Utility are summarized below. Assets held in rabbi trusts are held by PG&E Corporation and not the Utility. Fair Value Measurements At December 31, 2021 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 289 $ — $ — $ — $ 289 Nuclear decommissioning trusts Short-term investments 22 — — — 22 Global equity securities 2,504 — — — 2,504 Fixed-income securities 1,158 866 — — 2,024 Assets measured at NAV — — — — 31 Total nuclear decommissioning trusts (2) 3,684 866 — — 4,581 Price risk management instruments (Note 10) Electricity — 9 214 6 229 Gas — 4 — 137 141 Total price risk management instruments — 13 214 143 370 Rabbi trusts Fixed-income securities — 104 — — 104 Life insurance contracts — 76 — — 76 Total rabbi trusts — 180 — — 180 Long-term disability trust Short-term investments 6 — — — 6 Assets measured at NAV — — — — 132 Total long-term disability trust 6 — — — 138 TOTAL ASSETS $ 3,979 $ 1,059 $ 214 $ 143 $ 5,558 Liabilities: Price risk management instruments (Note 10) Electricity $ — $ 11 $ 248 $ (24) $ 235 Gas — 10 — (3) 7 TOTAL LIABILITIES $ — $ 21 $ 248 $ (27) $ 242 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. (2) Represents amount before deducting $783 million, primarily related to deferred taxes on appreciation of investment value. Fair Value Measurements At December 31, 2020 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 470 $ — $ — $ — $ 470 Nuclear decommissioning trusts Short-term investments 27 — — — 27 Global equity securities 2,398 — — — 2,398 Fixed-income securities 924 835 — — 1,759 Assets measured at NAV — — — — 25 Total nuclear decommissioning trusts (2) 3,349 835 — — 4,209 Price risk management instruments (Note 10) Electricity — 2 166 2 170 Gas — 1 — 113 114 Total price risk management instruments — 3 166 115 284 Rabbi trusts Fixed-income securities — 106 — — 106 Life insurance contracts — 79 — — 79 Total rabbi trusts — 185 — — 185 Long-term disability trust Short-term investments 9 — — — 9 Assets measured at NAV — — — — 158 Total long-term disability trust 9 — — — 167 TOTAL ASSETS $ 3,828 $ 1,023 $ 166 $ 115 $ 5,315 Liabilities: Price risk management instruments (Note 10) Electricity — 1 238 (25) 214 Gas — 3 — — 3 TOTAL LIABILITIES $ — $ 4 $ 238 $ (25) $ 217 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. (2) Represents amount before deducting $671 million, primarily related to deferred taxes on appreciation of investment value. Valuation Techniques The following describes the valuation techniques used to measure the fair value of the assets and liabilities shown in the tables above. There are no restrictions on the terms and conditions upon which the investments may be redeemed. There were no material transfers between any levels for the years ended December 31, 2021 and 2020. Trust Assets Assets Measured at Fair Value In general, investments held in the trusts are exposed to various risks, such as interest rate, credit, and market volatility risks. Nuclear decommissioning trust assets and other trust assets are composed primarily of equity and fixed-income securities and also include short-term investments that are money market funds valued at Level 1. Global equity securities primarily include investments in common stock that are valued based on quoted prices in active markets and are classified as Level 1. Fixed-income securities are primarily composed of U.S. government and agency securities, municipal securities, and other fixed-income securities, including corporate debt securities. U.S. government and agency securities primarily consist of U.S. Treasury securities that are classified as Level 1 because the fair value is determined by observable market prices in active markets. A market approach is generally used to estimate the fair value of fixed-income securities classified as Level 2 using evaluated pricing data such as broker quotes, for similar securities adjusted for observable differences. Significant inputs used in the valuation model generally include benchmark yield curves and issuer spreads. The external credit ratings, coupon rate, and maturity of each security are considered in the valuation model, as applicable. Assets Measured at NAV Using Practical Expedient Investments in the nuclear decommissioning trusts and the long-term disability trust that are measured at fair value using the NAV per share practical expedient have not been classified in the fair value hierarchy tables above. The fair value amounts are included in the tables above in order to reconcile to the amounts presented in the Consolidated Balance Sheets. These investments include commingled funds that are composed of equity securities traded publicly on exchanges as well as fixed-income securities that are composed primarily of U.S. government securities, credit securities and asset-backed securities. Price Risk Management Instruments Price risk management instruments include physical and financial derivative contracts, such as power purchase agreements, forwards, futures, swaps, options, and CRRs that are traded either on an exchange or over-the-counter. Power purchase agreements, forwards, and swaps are valued using a discounted cash flow model. Exchange-traded futures that are valued using observable market forward prices for the underlying commodity are classified as Level 1. Over-the-counter forwards and swaps that are identical to exchange-traded futures, or are valued using forward prices from broker quotes that are corroborated with market data are classified as Level 2. Exchange-traded options are valued using observable market data and market-corroborated data and are classified as Level 2. Long-dated power purchase agreements that are valued using significant unobservable data are classified as Level 3. These Level 3 contracts are valued using either estimated basis adjustments from liquid trading points or techniques, including extrapolation from observable prices, when a contract term extends beyond a period for which market data is available. The Utility utilizes models to derive pricing inputs for the valuation of the Utility’s Level 3 instruments using pricing inputs from brokers and historical data. The Utility holds CRRs to hedge the financial risk of CAISO-imposed congestion charges in the day-ahead market. Limited market data is available in the CAISO auction and between auction dates; therefore, the Utility utilizes historical prices to forecast forward prices. CRRs are classified as Level 3. Level 3 Measurements and Uncertainty Analysis Inputs used and the fair value of Level 3 instruments are reviewed period-over-period and compared with market conditions to determine reasonableness. Significant increases or decreases in any of those inputs would result in a significantly higher or lower fair value, respectively. All reasonable costs related to Level 3 instruments are expected to be recoverable through rates; therefore, there is no impact to net income resulting from changes in the fair value of these instruments. See Note 10 above. Fair Value at (in millions) At December 31, 2021 Valuation Unobservable Fair Value Measurement Assets Liabilities Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 188 $ 93 Market approach CRR auction prices $ (40.77) - 2,265.94 / 0.40 Power purchase agreements $ 26 $ 155 Discounted cash flow Forward prices $ (7.97) - 256.20 / 47.17 (1) Represents price per megawatt-hour. (2) Unobservable inputs were weighted by the relative fair value of the instruments. Fair Value at (in millions) At December 31, 2020 Valuation Unobservable Fair Value Measurement Assets Liabilities Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 153 $ 74 Market approach CRR auction prices $ (320.25) - 320.25 / 0.30 Power purchase agreements $ 13 $ 164 Discounted cash flow Forward prices $ 12.56 - 148.30 / 35.52 (1) Represents price per megawatt-hour. (2) Unobservable inputs were weighted by the relative fair value of the instruments. Level 3 Reconciliation The following table presents the reconciliation for Level 3 price risk management instruments for the years ended December 31, 2021 and 2020, respectively: Price Risk Management Instruments (in millions) 2021 2020 Asset (liability) balance as of January 1 $ (72) $ 5 Net realized and unrealized gains: Included in regulatory assets and liabilities or balancing accounts (1) 38 (77) Asset (liability) balance as of December 31 $ (34) $ (72) (1) The costs related to price risk management activities are fully passed through to customers in rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted. Financial Instruments PG&E Corporation and the Utility use the following methods and assumptions in estimating fair value for financial instruments: the fair values of cash, net accounts receivable, short-term borrowings, accounts payable, customer deposits, and the Utility’s variable rate pollution control bond loan agreements approximate their carrying values at December 31, 2021 and 2020, as they are short-term in nature. The carrying amount and fair value of PG&E Corporation’s and the Utility’s long-term debt instruments were as follows (the table below excludes financial instruments with carrying values that approximate their fair values): At December 31, 2021 2020 (in millions) Carrying Amount Level 2 Fair Value Carrying Amount Level 2 Fair Value Debt (Note 5) PG&E Corporation $ 4,619 $ 4,796 $ 1,901 $ 2,175 Utility 31,816 35,803 29,664 32,632 Nuclear Decommissioning Trust Investments The following table provides a summary of equity securities and available-for-sale debt securities: (in millions) Amortized Total Total Total Fair As of December 31, 2021 Nuclear decommissioning trusts Short-term investments $ 22 $ — $ — $ 22 Global equity securities 479 2,066 (10) 2,535 Fixed-income securities 1,938 98 (12) 2,024 Total (1) $ 2,439 $ 2,164 $ (22) $ 4,581 As of December 31, 2020 Nuclear decommissioning trusts Short-term investments $ 27 $ — $ — $ 27 Global equity securities 543 1,881 (1) 2,423 Fixed-income securities 1,610 152 (3) 1,759 Total (1) $ 2,180 $ 2,033 $ (4) $ 4,209 (1) Represents amounts before deducting $783 million and $671 million at December 31, 2021 and 2020, respectively, primarily related to deferred taxes on appreciation of investment value. The fair value of fixed-income securities by contractual maturity is as follows: As of (in millions) December 31, 2021 Less than 1 year $ 97 1–5 years 495 5–10 years 480 More than 10 years 952 Total maturities of fixed-income securities $ 2,024 The following table provides a summary of activity for the fixed-income and equity securities: (in millions) 2021 2020 2019 Proceeds from sales and maturities of nuclear decommissioning investments $ 1,678 $ 1,518 $ 956 Gross realized gains on securities 286 159 69 Gross realized losses on securities (19) (41) (14)

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	12 Months Ended
EMPLOYEE BENEFIT PLANS	Dec. 31, 2021
Employee Benefit and Share-based Payment Arrangement, Noncash Expense [Abstract]
EMPLOYEE BENEFIT PLANS	EMPLOYEE BENEFIT PLANS Pension Plan and Postretirement Benefits Other than Pensions (“PBOP”) PG&E Corporation and the Utility sponsor a non-contributory defined benefit pension plan for eligible employees hired before December 31, 2012 and a cash balance plan for those eligible employees hired after this date or who made a one-time election to participate (“Pension Plan”). Certain trusts underlying these plans are qualified trusts under the IRC. If certain conditions are met, PG&E Corporation and the Utility can deduct payments made to the qualified trusts, subject to certain limitations. PG&E Corporation’s and the Utility’s funding policy is to contribute tax-deductible amounts, consistent with applicable regulatory decisions and federal minimum funding requirements. On an annual basis, the Utility funds the pension plan up to the amount it is authorized to recover through rates. PG&E Corporation and the Utility also sponsor contributory postretirement medical plans for retirees and their eligible dependents, and non-contributory postretirement life insurance plans for eligible employees and retirees. PG&E Corporation and the Utility use a fiscal year-end measurement date for all plans. Change in Plan Assets, Benefit Obligations, and Funded Status The following tables show the reconciliation of changes in plan assets, benefit obligations, and the plans’ aggregate funded status for pension benefits and other benefits for PG&E Corporation during 2021 and 2020: Pension Plan (in millions) 2021 2020 Change in plan assets: Fair value of plan assets at beginning of year $ 20,759 $ 18,547 Actual return on plan assets 1,693 2,736 Company contributions 335 343 Benefits and expenses paid (892) (867) Fair value of plan assets at end of year $ 21,895 $ 20,759 Change in benefit obligation: Benefit obligation at beginning of year $ 23,172 $ 20,525 Service cost for benefits earned 587 530 Interest cost 645 713 Actuarial (gain) loss (1) (752) 2,271 Plan amendments — — Benefits and expenses paid (893) (867) Benefit obligation at end of year (2) $ 22,759 $ 23,172 Funded Status: Current liability $ (9) $ (3) Noncurrent liability (856) (2,410) Net liability at end of year $ (865) $ (2,413) (1) The actuarial gain for the year ended December 31, 2021 was due to an increase in the discount rate used to measure the projected benefit obligation, offset by unfavorable changes in the demographic assumptions. The actuarial loss for the year ended December 31, 2020 was due to a decrease in the discount rate used to measure the projected benefit obligation. (2) PG&E Corporation’s accumulated benefit obligation was $20.4 billion and $20.7 billion at December 31, 2021 and 2020, respectively. Postretirement Benefits Other than Pensions (in millions) 2021 2020 Change in plan assets: Fair value of plan assets at beginning of year $ 2,995 $ 2,678 Actual return on plan assets 193 379 Company contributions 10 26 Plan participant contribution 80 81 Benefits and expenses paid (176) (169) Fair value of plan assets at end of year $ 3,102 $ 2,995 Change in benefit obligation: Benefit obligation at beginning of year $ 1,876 $ 1,832 Service cost for benefits earned 63 61 Interest cost 51 63 Actuarial gain (1) (152) (14) Benefits and expenses paid (156) (149) Federal subsidy on benefits paid 4 3 Plan participant contributions 80 80 Benefit obligation at end of year $ 1,766 $ 1,876 Funded Status: (2) Noncurrent asset $ 1,340 $ 1,153 Noncurrent liability (4) (34) Net asset at end of year $ 1,336 $ 1,119 (1) The actuarial gain for the year ended December 31, 2021 was primarily due to an increase in the discount rate used to measure the accumulated benefit obligations and favorable claims cost changes. The actuarial gain for the year ended December 31, 2020 was primarily due to favorable changes in the demographic and medical cost assumptions, offset by a decrease in the discount rate used to measure the projected benefit obligation. (2) At December 31, 2021 and 2020, the postretirement medical plan was in an overfunded position and the postretirement life insurance plan was in an underfunded position. The projected benefit obligation and the fair value of plan assets for the postretirement life insurance plan were $363 million and $359 million as of December 31, 2021, and $377 million and $343 million as of December 31, 2020, respectively. There was no material difference between PG&E Corporation and the Utility for the information disclosed above. Components of Net Periodic Benefit Cost PG&E Corporation and the Utility sponsor a non-contributory defined benefit pension plan and cash balance plan. Both plans are included in “Pension Benefits” below. Post-retirement medical and life insurance plans are included in “Other Benefits” below. Net periodic benefit cost as reflected in PG&E Corporation’s Consolidated Statements of Income was as follows: Pension Plan (in millions) 2021 2020 2019 Service cost for benefits earned (1) $ 587 $ 530 $ 443 Interest cost 645 713 758 Expected return on plan assets (1,046) (1,044) (906) Amortization of prior service cost (6) (6) (6) Amortization of net actuarial loss 6 3 3 Net periodic benefit cost 186 196 292 Less: transfer to regulatory account (2) 147 136 42 Total expense recognized $ 333 $ 332 $ 334 (1) A portion of service costs are capitalized pursuant to ASU 2017-07. (2) The Utility recorded these amounts to a regulatory account as they are probable of recovery through future rates. Postretirement Benefits Other than Pensions (in millions) 2021 2020 2019 Service cost for benefits earned (1) $ 63 $ 61 $ 56 Interest cost 51 63 76 Expected return on plan assets (137) (138) (123) Amortization of prior service cost 14 14 14 Amortization of net actuarial loss (33) (21) (3) Net periodic benefit cost $ (42) $ (21) $ 20 (1) A portion of service costs are capitalized pursuant to ASU 2017-07. Non-service costs are reflected in Other income, net on the Consolidated Statements of Income. Service costs are reflected in Operating and maintenance on the Consolidated Statements of Income. There was no material difference between PG&E Corporation and the Utility for the information disclosed above. Components of Accumulated Other Comprehensive Income PG&E Corporation and the Utility record unrecognized prior service costs and unrecognized gains and losses related to pension and post-retirement benefits other than pension as components of accumulated other comprehensive income, net of tax. In addition, regulatory adjustments are recorded in the Consolidated Statements of Income and Consolidated Balance Sheets to reflect the difference between expense or income calculated in accordance with GAAP for accounting purposes and expense or income for ratemaking purposes, which is based on authorized plan contributions. For pension benefits, a regulatory asset or liability is recorded for amounts that would otherwise be recorded to accumulated other comprehensive income. For post-retirement benefits other than pension, the Utility generally records a regulatory liability for amounts that would otherwise be recorded to accumulated other comprehensive income. As the Utility is unable to record a regulatory asset for these other benefits, the charge remains in accumulated other comprehensive income (loss). Valuation Assumptions The following weighted average year-end actuarial assumptions were used in determining the plans’ projected benefit obligations and net benefit costs. Pension Plan PBOP Plans December 31, December 31, 2021 2020 2019 2021 2020 2019 Discount rate 3.03 % 2.77 % 3.46 % 2.97 - 3.04% 2.67 - 2.80 % 3.37 - 3.47% Rate of future compensation increases 3.80 % 3.80 % 3.90 % N/A N/A N/A Expected return on plan assets 5.50 % 5.10 % 5.70 % 3.30 - 6.40% 3.10 - 6.10 % 3.50 - 6.60% Interest crediting rate for cash balance plan 1.95 % 1.95 % 2.11 % N/A N/A N/A The assumed health care cost trend rate as of December 31, 2021 was 6.0%, gradually decreasing to the ultimate trend rate of approximately 4.5% in 2028 and beyond. Expected rates of return on plan assets were developed by estimating future stock and bond returns and then applying these returns to the target asset allocations of the employee benefit plan trusts, resulting in a weighted average rate of return on plan assets. Returns on fixed-income debt investments were projected based on real maturity and credit spreads added to a long-term inflation rate. Returns on equity investments were projected based on estimates of dividend yield and real earnings growth added to a long-term inflation rate. For the pension plan, the assumed return of 5.5% compares to a ten-year actual return of 9.6%. The rate used to discount pension benefits and other benefits was based on a yield curve developed from market data of over approximately 817 Aa-grade non-callable bonds at December 31, 2021. This yield curve has discount rates that vary based on the duration of the obligations. The estimated future cash flows for the pension benefits and other benefit obligations were matched to the corresponding rates on the yield curve to derive a weighted average discount rate. Investment Policies and Strategies The financial position of PG&E Corporation’s and the Utility’s funded status is the difference between the fair value of plan assets and projected benefit obligations. Volatility in funded status occurs when asset values change differently from liability values and can result in fluctuations in costs in financial reporting, as well as the amount of minimum contributions required under the Employee Retirement Income Security Act of 1974, as amended. PG&E Corporation’s and the Utility’s investment policies and strategies are designed to increase the ratio of trust assets to plan liabilities at an acceptable level of funded status volatility. The trusts’ asset allocations are meant to manage volatility, reduce costs, and diversify its holdings. Interest rate, credit, and equity risk are the key determinants of PG&E Corporation’s and the Utility’s funded status volatility. In addition to affecting the trusts’ fixed income portfolio market values, interest rate changes also influence liability valuations as discount rates move with current bond yields. To manage volatility, PG&E Corporation’s and the Utility’s trusts hold significant allocations in long maturity fixed-income investments. Although they contribute to funded status volatility, equity investments are held to reduce long-term funding costs due to their higher expected return. Real assets and absolute return investments are held to diversify the trust’s holdings in equity and fixed-income investments by exhibiting returns with low correlation to the direction of these markets. Real assets include global real estate investment trusts (“REITS”), global listed infrastructure equities, and private real estate funds. Absolute return investments include hedge fund portfolios. Derivative instruments such as equity index futures are used to meet target equity exposure. Derivative instruments, such as equity index futures and U.S. treasury futures, are also used to rebalance the fixed income/equity allocation of the pension’s portfolio. Foreign currency exchange contracts are used to hedge a portion of the non U.S. dollar exposure of global equity investments. The target asset allocation percentages for major categories of trust assets for pension and other benefit plans are as follows: Pension Plan PBOP Plans 2022 2021 2020 2022 2021 2020 Global equity securities 30 % 30 % 30 % 26 % 36 % 28 % Absolute return 2 % 2 % 2 % 1 % 1 % 2 % Real assets 8 % 8 % 8 % 3 % 5 % 8 % Fixed-income securities 60 % 60 % 60 % 70 % 58 % 62 % Total 100 % 100 % 100 % 100 % 100 % 100 % PG&E Corporation and the Utility apply a risk management framework for managing the risks associated with employee benefit plan trust assets. The guiding principles of this risk management framework are the clear articulation of roles and responsibilities, appropriate delegation of authority, and proper accountability and documentation. Trust investment policies and investment manager guidelines include provisions designed to ensure prudent diversification, manage risk through appropriate use of physical direct asset holdings and derivative securities, and identify permitted and prohibited investments. Fair Value Measurements The following tables present the fair value of plan assets for pension and other benefits plans by major asset category at December 31, 2021 and 2020. Fair Value Measurements At December 31, 2021 2020 (in millions) Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Pension Plan: Short-term investments $ 552 $ 255 $ — $ 807 $ 334 $ 408 $ — $ 742 Global equity securities 2,074 424 — 2,498 1,875 — — 1,875 Absolute Return — 1 — 1 1 1 — 2 Real assets 632 — — 632 517 — — 517 Fixed-income securities 2,729 7,388 27 10,144 2,467 7,154 12 9,633 Assets measured at NAV — — — 7,972 — — — 8,224 Total $ 5,987 $ 8,068 $ 27 $ 22,054 $ 5,194 $ 7,563 $ 12 $ 20,993 PBOP Plans: Short-term investments $ 31 $ — $ — $ 31 $ 37 $ — $ — $ 37 Global equity securities 105 — — 105 173 — — 173 Real assets 34 — — 34 54 — — 54 Fixed-income securities 776 875 1 1,652 481 715 1 1,197 Assets measured at NAV — — — 1,296 — — — 1,549 Total $ 946 $ 875 $ 1 $ 3,118 $ 745 $ 715 $ 1 $ 3,010 Total plan assets at fair value $ 25,172 $ 24,003 In addition to the total plan assets disclosed at fair value in the table above, the trusts had other net liabilities of $175 million and $249 million at December 31, 2021 and 2020, respectively, comprised primarily of cash, accounts receivable, deferred taxes, and accounts payable. Valuation Techniques The following describes the valuation techniques used to measure the fair value of the assets and liabilities shown in the table above. All investments that are valued using a NAV per share can be redeemed quarterly with a notice not to exceed 90 days. Short-Term Investments Short-term investments consist primarily of commingled funds across government, credit, and asset-backed sectors. These securities are categorized as Level 1 and Level 2 assets. Global Equity Securities The global equity category includes investments in common stock and equity-index futures. Equity investments in common stock are actively traded on public exchanges and are therefore considered Level 1 assets. These equity investments are generally valued based on unadjusted prices in active markets for identical securities. Equity-index futures are valued based on unadjusted prices in active markets and are Level 1 assets. Real Assets The real asset category includes portfolios of commodity futures, global REITS, global listed infrastructure equities, and private real estate funds. The commodity futures, global REITS, and global listed infrastructure equities are actively traded on a public exchange and are therefore considered Level 1 assets. Fixed-Income Securities Fixed-income securities are primarily composed of U.S. government and agency securities, municipal securities, and other fixed-income securities, including corporate debt securities. U.S. government and agency securities primarily consist of U.S. Treasury securities that are classified as Level 1 because the fair value is determined by observable market prices in active markets. A market approach is generally used to estimate the fair value of debt securities classified as Level 2 using evaluated pricing data such as broker quotes, for similar securities adjusted for observable differences. Significant inputs used in the valuation model generally include benchmark yield curves and issuer spreads. The external credit ratings, coupon rate, and maturity of each security are considered in the valuation model, as applicable. Assets Measured at NAV Using Practical Expedient Investments in the trusts that are measured at fair value using the NAV per share practical expedient have not been classified in the fair value hierarchy tables above. The fair value amounts are included in the tables above in order to reconcile to the amounts presented in the Consolidated Balance Sheets. These investments include commingled funds that are composed of equity securities traded publicly on exchanges, fixed-income securities that are composed primarily of U.S. government securities, credit securities and asset-backed securities, and real assets and absolute return investments that are held to diversify the trust’s holdings in equity and fixed-income securities. Transfers Between Levels No material transfers between levels occurred in the years ended December 31, 2021 and 2020. Level 3 Reconciliation The following table is a reconciliation of changes in the fair value of instruments for the pension plan that have been classified as Level 3 for the years ended December 31, 2021 and 2020: (in millions) For the year ended December 31, 2021 Fixed-Income Balance at beginning of year $ 12 Actual return on plan assets: Relating to assets still held at the reporting date 6 Relating to assets sold during the period (7) Purchases, issuances, sales, and settlements: Purchases 22 Settlements (6) Balance at end of year $ 27 (in millions) For the year ended December 31, 2020 Fixed-Income Balance at beginning of year $ 15 Actual return on plan assets: Relating to assets still held at the reporting date 2 Relating to assets sold during the period (3) Purchases, issuances, sales, and settlements: Purchases 11 Settlements (13) Balance at end of year $ 12 There were no material transfers out of Level 3 in 2021 and 2020. Cash Flow Information Employer Contributions PG&E Corporation and the Utility contributed $335 million to the pension benefit plans and $10 million to the other benefit plans in 2021. These contributions are consistent with PG&E Corporation’s and the Utility’s funding policy, which is to contribute amounts that are tax-deductible and consistent with applicable regulatory decisions and federal minimum funding requirements. None of these pension or other benefits were subject to a minimum funding requirement requiring a cash contribution in 2021. The Utility’s pension benefits met all the funding requirements under Employee Retirement Income Security Act. PG&E Corporation and the Utility expect to make total contributions of approximately $327 million and $15 million to the pension plan and other postretirement benefit plans, respectively, for 2022. Benefits Payments and Receipts As of December 31, 2021, the estimated benefits expected to be paid and the estimated federal subsidies expected to be received in each of the next five fiscal years, and in aggregate for the five fiscal years thereafter, are as follows: (in millions) Pension PBOP Federal 2022 869 81 (3) 2023 954 85 (3) 2024 988 89 (3) 2025 1018 88 (3) 2026 1,046 91 (3) Thereafter in the succeeding five years 5,533 466 (3) There were no material differences between the estimated benefits expected to be paid by PG&E Corporation and paid by the Utility for the years presented above. There were also no material differences between the estimated subsidies expected to be received by PG&E Corporation and received by the Utility for the years presented above. Retirement Savings Plan PG&E Corporation sponsors a retirement savings plan, which qualifies as a 401(k) defined contribution benefit plan under the Internal Revenue Code 1986, as amended. This plan permits eligible employees to make pre-tax and after-tax contributions into the plan, and provide for employer contributions to be made to eligible participants. Total expenses recognized for defined contribution benefit plans reflected in PG&E Corporation’s Consolidated Statements of Income were $133 million, $119 million, and $109 million in 2021, 2020, and 2019, respectively. Beginning January 1, 2019 PG&E Corporation changed its default matching contributions under its 401(k) plan from PG&E Corporation common stock to cash. Beginning in March 2019, at PG&E Corporation’s directive, the 401(k) plan trustee began purchasing new shares in the PG&E Corporation common stock fund on the open market rather than directly from PG&E Corporation. There were no material differences between the employer contribution expense for PG&E Corporation and the Utility for the years presented above.

RELATED PARTY AGREEMENTS AND TR

RELATED PARTY AGREEMENTS AND TRANSACTIONS	12 Months Ended
RELATED PARTY AGREEMENTS AND TRANSACTIONS	Dec. 31, 2021
Related Party Transactions [Abstract]
RELATED PARTY AGREEMENTS AND TRANSACTIONS	RELATED PARTY AGREEMENTS AND TRANSACTIONS The Utility and other subsidiaries provide and receive various services to and from their parent, PG&E Corporation, and among themselves. The Utility and PG&E Corporation exchange administrative and professional services in support of operations. Services provided directly to PG&E Corporation by the Utility are priced at the higher of fully loaded cost (i.e., direct cost of good or service and allocation of overhead costs) or fair market value, depending on the nature of the services. Services provided directly to the Utility by PG&E Corporation are generally priced at the lower of fully loaded cost or fair market value, depending on the nature and value of the services. PG&E Corporation also allocates various corporate administrative and general costs to the Utility and other subsidiaries using agreed-upon allocation factors, including the number of employees, operating and maintenance expenses, total assets, and other cost allocation methodologies. Management believes that the methods used to allocate expenses are reasonable and meet the reporting and accounting requirements of its regulatory agencies. The Utility’s significant related party transactions were: Year Ended December 31, (in millions) 2021 2020 2019 Utility revenues from: Administrative services provided to PG&E Corporation $ 3 $ 3 $ 4 Utility expenses from: Administrative services received from PG&E Corporation $ 82 $ 108 $ 107 Utility employee benefit due to PG&E Corporation 39 34 42 At December 31, 2021 and 2020, the Utility had receivables of $173 million and $35 million, respectively, from PG&E Corporation included in Accounts receivable – other and Noncurrent assets – other on the Utility’s Consolidated Balance Sheets, and payables of $19 million and $46 million, respectively, to PG&E Corporation included in accounts payable – other on the Utility’s Consolidated Balance Sheets. On August 11, 2021, PG&E Corporation borrowed $145 million from the Utility under an interest bearing 364-day intercompany note due August 10, 2022. As of December 31, 2021, the intercompany note is reflected in Accounts receivable - other on the Utility’s Consolidated Balance Sheet and is eliminated upon consolidation of PG&E Corporation’s Consolidated Balance Sheet. For more information, see “Intercompany Note Payable” in Note 5 above.

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES	12 Months Ended
WILDFIRE-RELATED CONTINGENCIES	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
WILDFIRE-RELATED CONTINGENCIES	WILDFIRE-RELATED CONTINGENCIES Liability Overview PG&E Corporation and the Utility have significant contingencies arising from their operations, including contingencies related to wildfires. A provision for a loss contingency is recorded when it is both probable that a liability has been incurred and the amount of the liability can be reasonably estimated. PG&E Corporation and the Utility evaluate which potential liabilities are probable and the related range of reasonably estimated losses and record a charge that reflects their best estimate or the lower end of the range, if there is no better estimate. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of losses is estimable, often involves a series of complex judgments about future events. Loss contingencies are reviewed quarterly, and estimates are adjusted to reflect the impact of all known information, such as negotiations (including those during mediations with claimants), discovery, settlements and payments, rulings, advice of legal counsel, and other information and events pertaining to a particular matter. PG&E Corporation’s and the Utility’s provision for loss and expense excludes anticipated legal costs, which are expensed as incurred. PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows may be materially affected by the outcome of the following matters. The process for estimating losses associated with potential claims related to wildfires requires management to exercise significant judgment based on a number of assumptions and subjective factors, including the factors identified above and estimates based on currently available information and prior experience with wildfires. As more information becomes available, including from potential claimants as litigation or resolution efforts progress, management estimates and assumptions regarding the potential financial impacts of wildfire events may change. Potential liabilities related to wildfires depend on various factors, including the cause of the fire, contributing causes of the fire (including alternative potential origins, weather- and climate-related issues, and forest management and fire suppression practices), the number, size and type of structures damaged or destroyed, the contents of such structures and other personal property damage, the number and types of trees damaged or destroyed, attorneys’ fees for claimants, the nature and extent of any personal injuries, including the loss of lives, the amount of fire suppression and clean-up costs, other damages the Utility may be responsible for if found negligent, and the amount of any penalties, fines, or restitution that may be imposed by courts or other governmental entities. Criminal charges have been filed against the Utility in connection with the 2019 Kincade fire and the 2020 Zogg fire. Under California law (including Penal Code section 1202.4), if the Utility were convicted of any of the charges, the sentencing court must order the Utility to “make restitution to the victim or victims in an amount established by court order” that is “sufficient to fully reimburse the victim or victims for every determined economic loss incurred as the result of” the Utility’s underlying conduct, in addition to interest and the victim’s or victims’ attorneys’ fees. This requirement for full reimbursement of economic loss is not waivable by either the government or the victims and is not offset by any compensation that the victims have received or may receive from their insurance carriers. If convicted of any of the charges, the Utility could be subject to fines, penalties, and restitution to victims for their economic losses (including property damage, medical and mental health expenses, lost wages, lost profits, attorneys’ fees and interest), as well as non-monetary remedies such as oversight requirements. In the event that the Utility were convicted of certain charges in connection with the 2019 Kincade fire or 2020 Zogg fire, the Utility currently believes that, depending on which charges it were to be convicted of, its total losses associated with such fire would materially exceed the accrued estimated liabilities that PG&E Corporation and the Utility have recorded to reflect the lower end of the range of the reasonably estimable range of losses. The Utility is currently unable to determine a reasonable estimate of the amount of such additional losses. The Utility does not expect that any of its liability insurance would be available to cover restitution payments ordered by the courts presiding over the criminal proceedings. PG&E Corporation and the Utility are aware of numerous civil complaints related to the following wildfire events and expect that they may receive further such complaints. The complaints include claims based on multiple theories of liability, including inverse condemnation, negligence, violations of the Public Utilities Code, violations of the Health & Safety Code, premises liability, trespass, public nuisance and private nuisance. The plaintiffs in each action principally assert that PG&E Corporation’s and the Utility’s alleged failure to properly maintain, inspect, and de-energize their transmission lines was the cause of the relevant wildfire. The timing and outcome for resolution of any such claims or investigations are uncertain. The Utility believes it will continue to receive additional information from potential claimants in connection with these wildfire events as litigation or resolution efforts progress. Any such additional information may potentially allow PG&E Corporation and the Utility to refine the estimates of their accrued losses and may result in changes to the accrual depending on the information received. PG&E Corporation and the Utility intend to vigorously defend themselves against both criminal charges and civil complaints. If the Utility’s facilities, such as its electric distribution and transmission lines, are judicially determined to be the substantial cause of the following matters, and the doctrine of inverse condemnation applies, the Utility could be liable for property damage, business interruption, interest and attorneys’ fees without having been found negligent. California courts have imposed liability under the doctrine of inverse condemnation in legal actions brought by property holders against utilities on the grounds that losses borne by the person whose property was damaged through a public use undertaking should be spread across the community that benefited from such undertaking, and based on the assumption that utilities have the ability to recover these costs through rates. Further, California courts have determined that the doctrine of inverse condemnation is applicable regardless of whether the CPUC ultimately allows recovery by the utility for any such costs. The CPUC may decide not to authorize cost recovery even if a court decision were to determine that the Utility is liable as a result of the application of the doctrine of inverse condemnation. In addition to claims for property damage, business interruption, interest and attorneys’ fees under inverse condemnation, PG&E Corporation and the Utility could be liable for fire suppression costs, evacuation costs, medical expenses, personal injury damages, punitive damages and other damages under other theories of liability in connection with the following wildfire events, including if PG&E Corporation or the Utility were found to have been negligent. PG&E Corporation and the Utility currently believe that it is reasonably possible that the amount of loss could be greater than the accrued estimated amounts but are unable to reasonably estimate the additional loss and the upper end of the range because, as described above, there are a number of unknown facts and legal considerations that may impact the amount of any potential liability, including the total scope and nature of claims that may be asserted against PG&E Corporation and the Utility and the outcome of the criminal proceedings initiated against the Utility. If the liability for wildfires were to exceed $1.0 billion in the aggregate in any Coverage Year, the Utility may be eligible to make a claim to the Wildfire Fund under AB 1054 to satisfy settled or finally adjudicated eligible claims in excess of such amount, except that claims related to the 2019 Kincade fire would be subject to the 40% limitation on the allowed amount of claims arising before emergence from bankruptcy. PG&E Corporation and the Utility intend to continue to review the available information and other information as it becomes available, including evidence in the possession of Cal Fire or the relevant district attorney’s office, evidence from or held by other parties, claims that have not yet been submitted, and additional information about the nature and extent of personal and business property damages and losses, the nature, number and severity of personal injuries, and information made available through the discovery process. 2019 Kincade Fire According to Cal Fire, on October 23, 2019 at approximately 9:27 p.m. Pacific Time, a wildfire began northeast of Geyserville in Sonoma County, California (the “2019 Kincade fire”), located in the service territory of the Utility. According to a Cal Fire incident update dated March 3, 2020, 3:35 p.m. Pacific Time, the 2019 Kincade fire consumed 77,758 acres and resulted in no fatalities, four first responder injuries, 374 structures destroyed, and 60 structures damaged. In connection with the 2019 Kincade fire, state and local officials issued numerous mandatory evacuation orders and evacuation warnings. Based on County of Sonoma information, PG&E Corporation and the Utility understand that the geographic zones subject to either a mandatory evacuation order or an evacuation warning between October 23, 2019 and November 4, 2019 included approximately 200,000 persons. On July 16, 2020, Cal Fire issued a press release with its determination that the Utility’s equipment caused the 2019 Kincade fire. On April 6, 2021, the Sonoma County District Attorney’s office filed the Kincade Complaint charging the Utility with five felonies and 28 misdemeanors related to the 2019 Kincade fire. On April 6, 2021, PG&E Corporation announced that it disputed the charges in the Kincade Complaint. It further announced that it would accept Cal Fire’s finding that a Utility transmission line caused the 2019 Kincade fire. On May 11, 2021, the Utility filed a demurrer to 25 of the 33 counts contained in the Kincade Complaint. At a hearing on September 9, 2021, the Sonoma County Superior Court overruled the demurrer. The Utility pled not guilty to all charges on October 13, 2021. On January 28, 2022, the Sonoma County District Attorney’s Office filed the Kincade Amended Complaint, which replaces two felonies with five different felonies and drops six misdemeanor counts. On January 28, 2022, the court deemed the Utility’s demurrer and the court’s prior ruling as applying to 22 of the 30 counts in the Kincade Amended Complaint, and the Utility thereafter pled not guilty to all charges in the Kincade Amended Complaint. A preliminary hearing on the charges began on February 8, 2022. On December 2, 2021, the CPUC approved a settlement between the Safety Enforcement Division and the Utility (the “Kincade SED Settlement”). The Kincade SED Settlement resolves SED’s investigation into the 2019 Kincade fire and provides for the removal of approximately 70 transmission lines or portions of lines that are no longer in service and are de-energized but have not been removed as required by CPUC rules. The Kincade SED Settlement provides that (i) the Utility will pay $40 million to California’s General Fund; (ii) the Utility will remove permanently abandoned transmission lines over a ten-year period; and (iii) the Utility must incur $85 million of the costs of such work by December 31, 2024, and it may not seek recovery of this $85 million of costs. SED agreed to refrain from instituting enforcement proceedings against the Utility for not having removed the lines previously. The Kincade SED Settlement states that it does not constitute an admission by the Utility of violations of GOs or statutory requirements. In connection with the Kincade SED Settlement, PG&E Corporation and the Utility recorded a liability of $40 million reflected in Other current liabilities on the Consolidated Financial Statements for the period ended December 31, 2021. For the $85 million of cost of removal that the Utility will not seek recovery, the Utility expects to record such disallowances in 2022. On January 10, 2022, TURN filed an application for rehearing of the Kincade SED Settlement. On January 25, 2022, the Utility filed an opposition to the application for rehearing. As of February 3, 2022, PG&E Corporation and the Utility are aware of approximately 100 complaints on behalf of at least 2,605 plaintiffs related to the 2019 Kincade fire. The plaintiffs filed master complaints on July 16, 2021; PG&E Corporation’s and the Utility’s response was filed on August 16, 2021; and PG&E Corporation and the Utility filed a demurrer with respect to the plaintiffs’ inverse condemnation claims. On December 10, 2021, the court overruled the demurrer. In addition, on January 5, 2022, Cal Fire filed a complaint in the coordinated proceeding seeking to recover approximately $90 million for fire suppression and other costs incurred in connection with the 2019 Kincade fire. Following a November 5, 2021 hearing, the San Francisco County Superior Court set a trial date of November 7, 2022. Based on the current state of the law concerning inverse condemnation in California and the facts and circumstances available to PG&E Corporation and the Utility as of the date of this filing, including Cal Fire’s determination of the cause and the information gathered as part of PG&E Corporation’s and the Utility’s investigation, PG&E Corporation and the Utility believe it is probable that they will incur a loss in connection with the 2019 Kincade fire. PG&E Corporation and the Utility recorded a liability in the aggregate amount of $625 million for the year ended December 31, 2020 (before available insurance). Based on the facts and circumstances available to the Utility as of the filing of PG&E Corporation’s and the Utility’s Consolidated Financial Statements for the year ended December 31, 2021, including the status of negotiations with certain subrogation entities, PG&E Corporation and the Utility recorded an additional charge in 2021 for potential losses in connection with the 2019 Kincade fire of $175 million, for an aggregate liability of $800 million (before available insurance). The Utility’s accrued estimated losses do not include, among other things: (i) any amounts for potential penalties, fines, or restitution that may be imposed by courts or other governmental entities on PG&E Corporation or the Utility, (ii) any punitive damages, (iii) any amounts in respect of compensation claims by federal or state agencies other than state fire suppression costs, (iv) evacuation costs, or (v) any other amounts that are not reasonably estimable. The following table presents changes in the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimable range of losses for claims arising from the 2019 Kincade fire since December 31, 2019. Loss Accrual (in millions) Balance at December 31, 2019 $ — Accrued Losses 625 Payments — Balance at December 31, 2020 625 Accrued Losses 175 Payments (31) Balance at December 31, 2021 $ 769 The Utility has liability insurance coverage for third-party liability attributable to the 2019 Kincade fire in an aggregate amount of $430 million. As of December 31, 2021, the Utility has recorded an insurance receivable for the full amount of the $430 million. 2020 Zogg Fire According to Cal Fire, on September 27, 2020, at approximately 4:03 p.m. Pacific Time, a wildfire began in the area of Zogg Mine Road and Jenny Bird Lane, north of Igo in Shasta County, California (the “2020 Zogg fire”), located in the service territory of the Utility. According to a Cal Fire incident update dated October 16, 2020, 3:08 p.m. Pacific Time, the 2020 Zogg fire consumed 56,338 acres and resulted in four fatalities, one injury, 204 structures destroyed, and 27 structures damaged. On March 22, 2021, Cal Fire issued a press release with its determination that the 2020 Zogg fire was caused by a pine tree contacting electrical facilities owned and operated by the Utility located north of the community of Igo. On September 24, 2021, the Shasta County District Attorney’s Office filed the Zogg Complaint charging the Utility with 11 felonies and 20 misdemeanors related to the 2020 Zogg fire, the 2020 Daniel fire, the 2020 Ponder fire, and the 2021 Woody fire. On September 24, 2021, PG&E Corporation and the Utility announced that they disputed the charges in the Zogg Complaint. They further announced that they would accept Cal Fire’s finding that a Utility electric line caused the 2020 Zogg fire, even though PG&E Corporation and the Utility did not have access to all of the evidence that Cal Fire gathered. On November 18, 2021, the Utility filed a demurrer to 10 of the 31 counts contained in the Zogg Complaint. A hearing on the demurrer is set for April 4, 2022. Various other entities, which may include other law enforcement agencies, may also be investigating the fire. It is uncertain when any such investigations will be complete. As of February 3, 2022, PG&E Corporation and the Utility are aware of approximately 21 complaints on behalf of at least 382 plaintiffs related to the 2020 Zogg fire. The plaintiffs seek damages that include wrongful death, property damage, economic loss, punitive damages, exemplary damages, attorneys’ fees and other damages. The plaintiffs filed master complaints on August 6, 2021, and PG&E Corporation’s and the Utility’s answer was filed on September 7, 2021, and PG&E Corporation and the Utility filed a demurrer with respect to the plaintiffs’ inverse condemnation claims. On December 10, 2021, the court overruled the demurrer. At an October 4, 2021 hearing, the San Francisco County Superior Court set a trial date of February 6, 2023. In addition, PG&E Corporation and the Utility have been contacted by Cal Fire to accept service of a complaint filed against them for fire suppression costs incurred in connection with the 2020 Zogg fire. Based on the current state of the law concerning inverse condemnation in California and the facts and circumstances available to PG&E Corporation and the Utility as of the date of this filing, including Cal Fire’s determination of the cause and the information gathered as part of PG&E Corporation’s and the Utility’s investigation, PG&E Corporation and the Utility believe it is probable that they will incur a loss in connection with the 2020 Zogg fire. PG&E Corporation and the Utility recorded a liability in the aggregate amount of $275 million for the year ended December 31, 2020 (before available insurance). Based on the facts and circumstances available to the Utility as of the filing of the Consolidated Financial Statements for the year ended December 31, 2021, including the status of negotiations with certain agencies, subrogation entities, and individual plaintiffs, PG&E Corporation and the Utility recorded an additional charge in 2021 for potential losses in connection with the 2020 Zogg fire in the amount of $100 million, for an aggregate liability of $375 million (before available insurance). Following continued negotiations during the quarter ended December 31, 2021, PG&E Corporation and the Utility entered agreements with all but one of the insurance subrogation plaintiffs in the 2020 Zogg fire litigation to resolve their claims arising from the 2020 Zogg fire. The Utility’s accrued estimated losses do not include, among other things: (i) any amounts for potential penalties, fines, or restitution that may be imposed by courts or other governmental entities on PG&E Corporation or the Utility, (ii) any punitive damages, (iii) any amounts in respect of compensation claims by federal or state agencies other than state fire suppression costs, (iv) evacuation costs, or (v) any other amounts that are not reasonably estimable. The following table presents changes in the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimable range of losses for claims arising from the 2020 Zogg fire since December 31, 2019. Loss Accrual (in millions) Balance at December 31, 2019 $ — Accrued Losses 275 Payments — Balance at December 31, 2020 275 Accrued Losses 100 Payments (164) Balance at December 31, 2021 $ 211 The Utility has liability insurance for third-party liability attributable to the 2020 Zogg fire in an aggregate amount of $611 million. This amount is reduced from the $867.5 million of coverage disclosed in the 2020 Form 10-K due to the Utility’s commuting certain insurance policies in connection with its April 2021 wildfire liability insurance renewal. As of December 31, 2021, the Utility has recorded an insurance receivable for $337 million for probable insurance recoveries in connection with the 2020 Zogg fire, which equals the $375 million probable loss estimate less an initial self-insured retention of $60 million, plus $22 million in legal fees incurred. Recovery under the Utility’s insurance policies for the 2021 Dixie fire will reduce the amount of insurance proceeds available for the 2020 Zogg fire by the same amount. 2021 Dixie Fire According to Cal Fire, on July 13, 2021, at approximately 5:15 p.m. Pacific Time, a wildfire began in the Feather River Canyon near Cresta Dam (the “2021 Dixie fire”), located in the service territory of the Utility. According to a Cal Fire incident update, dated October 25, 2021, 7:46 a.m. Pacific Time, the 2021 Dixie fire consumed 963,309 acres and resulted in 1,329 structures destroyed (including 717 residential, 143 commercial, and 443 other structures), 95 structures damaged, and one fatality, which according to published reports was a fire fighter who passed away due to COVID-19 after returning home from the 2021 Dixie fire. On January 4, 2022, Cal Fire issued a press release with its determination that the 2021 Dixie fire was caused by a tree contacting electrical distribution lines owned and operated by the Utility. The Butte County, Plumas County, Shasta County, Lassen County and Tehama County District Attorneys’ Offices, as well as the SED and OEIS, are investigating the fire; various other entities, which may include other state and federal law enforcement agencies, may also be investigating the fire. The United States Attorney’s Office for the Eastern District of California issued a subpoena for documents as well. PG&E Corporation and the Utility are cooperating with the investigations. It is uncertain when any such investigations will be complete. PG&E Corporation and the Utility are also conducting their own investigation into the cause of the 2021 Dixie fire. This investigation is ongoing, and PG&E Corporation and the Utility do not have access to all of the evidence in the possession of Cal Fire or other third parties. As of February 3, 2022, PG&E Corporation and the Utility are aware of approximately 20 complaints on behalf of at least 1,005 plaintiffs related to the 2021 Dixie fire and expect that they may receive further such complaints. The plaintiffs seek damages that include property damage, economic loss, punitive damages, exemplary damages, attorneys’ fees and other damages. Based on the current state of the law concerning inverse condemnation in California and the facts and circumstances available to PG&E Corporation and the Utility as of the date of this filing, including Cal Fire’s determination of the cause and the information gathered as part of PG&E Corporation’s and the Utility’s investigation, PG&E Corporation and the Utility believe it is probable that they will incur a loss in connection with the 2021 Dixie fire. PG&E Corporation and the Utility recorded a liability in the aggregate amount of $1.15 billion for the year ended December 31, 2021 (before available recoveries). The Utility’s accrued estimated losses do not include, among other things: (i) any amounts for potential penalties, fines, or restitution that may be imposed by courts or other governmental entities on PG&E Corporation or the Utility, (ii) any punitive damages, (iii) any amounts in respect of compensation claims by federal or state agencies including for state or federal fire suppression costs and damages related to federal land, (iv) evacuation costs, or (v) any other amounts that are not reasonably estimable. As noted above, the aggregate estimated liability for claims in connection with the 2021 Dixie fire does not include potential claims for fire suppression costs from federal, state, county, or local agencies or damage to land and vegetation in national parks or national forests. As to these damages, PG&E Corporation and the Utility have not concluded that a loss is probable due to the incomplete information available to PG&E Corporation and the Utility as of the date of this filing as to facts pertinent to potential claims and defenses. Moreover, PG&E Corporation and the Utility are currently unable to reasonably estimate the range of possible losses for any such claims due to, among other factors, incomplete information as to facts pertinent to potential claims and defenses, as well as facts that would bear on the amount, type, and valuation of vegetation loss, potential reforestation, habitat loss, and other resources damaged or destroyed by the 2021 Dixie fire. PG&E Corporation and the Utility believe, however, that such losses could be significant with respect to fire suppression costs due to the size and duration of the 2021 Dixie fire and corresponding magnitude of fire suppression resources dedicated to fighting the 2021 Dixie fire and with respect to claims for damage to land and vegetation in national parks or national forests due to the very large number of acres of national park and national forests that were affected by the 2021 Dixie fire. According to the National Interagency Coordination Center Incident Management Situation Report dated October 29, 2021 at 7:30 a.m. Mountain Time, over $630 million of costs had been incurred in suppressing the 2021 Dixie fire. The Utility currently estimates that the fire burned approximately 70,000 acres of national parks and approximately 685,000 acres of national forests. The Utility has liability insurance coverage for third-party liability attributable to periods in which both the 2020 Zogg fire and 2021 Dixie fire occurred in an aggregate amount of $900 million. Recovery under the Utility’s insurance policies for the 2020 Zogg fire will reduce the amount of insurance proceeds available for the 2021 Dixie fire by the same amount. An immaterial decrease was recorded in the fourth quarter of 2021. As of December 31, 2021, the Utility has recorded an insurance receivable of $563 million for probable insurance recoveries in connection with the 2021 Dixie fire, which equals the aggregate $900 million of available insurance coverage for third-party liability attributable to the 2021 Dixie fire, less the $337 million insurance receivable recorded in connection with the 2020 Zogg fire. As of December 31, 2021, the Utility has recorded a Wildfire Fund receivable of $150 million for probable recoveries in connection with the 2021 Dixie fire. See “Wildfire Fund under AB 1054” below. The Utility has also recorded a $101 million reduction to its regulatory liability for wildfire-related claims costs that were determined to be probable of recovery through the FERC TO formula rate and a $347 million regulatory asset for costs that were determined to be probable of recovery through the WEMA. See “Regulatory Recovery” below. Decreases in the amount of the insurance receivable for the 2021 Dixie fire may also increase the amount that is probable of recovery through the FERC TO formula rate and the WEMA. An immaterial increase was recorded in the fourth quarter of 2021. Loss Recoveries PG&E Corporation and the Utility have recovery mechanisms available for wildfire liabilities including from insurance, customers, and the Wildfire Fund. PG&E Corporation and the Utility record a receivable for a recovery when it is deemed probable that recovery of a recorded loss will occur, and the Utility can reasonably estimate the amount or its range. While the Utility plans to seek recovery of all insured losses, it is unable to predict the ultimate amount and timing of such insurance recoveries. Total probable recoveries for the 2021 Dixie fire as of December 31, 2021 are: Potential Recovery Source (in millions) 2021 Dixie fire Insurance $ 563 FERC TO rates 101 WEMA 347 Wildfire Fund 150 Probable recoveries at December 31, 2021 $ 1,161 The Utility could be subject to significant liability in connection with these wildfire events. If such liability is not recoverable from insurance or the other mechanisms described herein, it could have a material impact on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows. Insurance Coverage In April 2021, the Utility purchased approximately $268 million in wildfire liability insurance coverage for the period from April 13, 2021 to April 1, 2022, and approximately $32 million in incremental wildfire liability reinsurance for the period from April 1, 2021 to April 1, 2022 at a cost of approximately $220 million. This coverage is in addition to approximately $11 million in existing wildfire liability reinsurance for the period from July 1, 2020 to July 1, 2021 and approximately $600 million in existing wildfire liability insurance purchased by the Utility in August 2020 for the period from August 1, 2020 to August 1, 2021. On August 1, 2021, the $600 million of existing wildfire liability coverage renewed on a 12-month term covering the period from August 1, 2021 to August 1, 2022 at a cost of approximately $516 million pursuant to multi-year policy terms. The Utility’s wildfire liability insurance is subject to an initial self-insured retention of $60 million. In June 2021, the Utility purchased approximately $535 million in non-wildfire liability coverage for the period from June 1, 2021 to April 1, 2022 at a cost of approximately $89 million. This coverage is in addition to approximately $140 million in existing non-wildfire liability insurance for the period from August 1, 2020 to August 1, 2021. In connection with the June 2021 renewal, the Utility procured an extension of this existing coverage to April 1, 2022 at a premium cost of approximately $30 million. The Utility also has $50 million in additional non-wildfire liability coverage available through one of its wildfire liability policies with shared limits. The Utility’s non-wildfire liability insurance is subject to an initial self-insured retention of $10 million. As of December 31, 2021, PG&E Corporation and the Utility had prepaid insurance of $358 million, reflected in Other current assets on the Consolidated Balance Sheets. Various coverage limitations applicable to different insurance layers could result in material uninsured costs in the future depending on the amount and type of damages resulting from covered events. In the Utility’s 2020 GRC proceeding, the CPUC also approved a settlement agreement provision that allows the Utility to recover annual insurance costs for up to $1.4 billion in general liability insurance coverage. For more information about the RTBA, see Note 4 above. Insurance Receivable Through December 31, 2021, PG&E Corporation and the Utility recorded $430 million for probable insurance recoveries in connection with the 2019 Kincade fire, $337 million for probable insurance recoveries in connection with the 2020 Zogg fire, and $563 million for probable insurance recoveries in connection with the 2021 Dixie fire. PG&E Corporation and the Utility intend to seek full recovery for all insured losses. The balances for insurance receivables with respect to wildfires are included in Other accounts receivable in PG&E Corporation’s and the Utility’s Consolidated Balance Sheets: Insurance Receivable (in millions) 2021 Dixie fire 2020 Zogg fire 2019 Kincade fire 2018 Camp fire 2017 Northern California wildfires 2015 Butte fire Total Balance at December 31, 2019 $ — $ — $ — $ 1,380 $ 808 $ 50 $ 2,238 Accrued insurance recoveries — 219 430 — — — 649 R

OTHER CONTINGENCIES AND COMMITM

OTHER CONTINGENCIES AND COMMITMENTS	12 Months Ended
OTHER CONTINGENCIES AND COMMITMENTS	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
OTHER CONTINGENCIES AND COMMITMENTS	WILDFIRE-RELATED CONTINGENCIES Liability Overview PG&E Corporation and the Utility have significant contingencies arising from their operations, including contingencies related to wildfires. A provision for a loss contingency is recorded when it is both probable that a liability has been incurred and the amount of the liability can be reasonably estimated. PG&E Corporation and the Utility evaluate which potential liabilities are probable and the related range of reasonably estimated losses and record a charge that reflects their best estimate or the lower end of the range, if there is no better estimate. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of losses is estimable, often involves a series of complex judgments about future events. Loss contingencies are reviewed quarterly, and estimates are adjusted to reflect the impact of all known information, such as negotiations (including those during mediations with claimants), discovery, settlements and payments, rulings, advice of legal counsel, and other information and events pertaining to a particular matter. PG&E Corporation’s and the Utility’s provision for loss and expense excludes anticipated legal costs, which are expensed as incurred. PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows may be materially affected by the outcome of the following matters. The process for estimating losses associated with potential claims related to wildfires requires management to exercise significant judgment based on a number of assumptions and subjective factors, including the factors identified above and estimates based on currently available information and prior experience with wildfires. As more information becomes available, including from potential claimants as litigation or resolution efforts progress, management estimates and assumptions regarding the potential financial impacts of wildfire events may change. Potential liabilities related to wildfires depend on various factors, including the cause of the fire, contributing causes of the fire (including alternative potential origins, weather- and climate-related issues, and forest management and fire suppression practices), the number, size and type of structures damaged or destroyed, the contents of such structures and other personal property damage, the number and types of trees damaged or destroyed, attorneys’ fees for claimants, the nature and extent of any personal injuries, including the loss of lives, the amount of fire suppression and clean-up costs, other damages the Utility may be responsible for if found negligent, and the amount of any penalties, fines, or restitution that may be imposed by courts or other governmental entities. Criminal charges have been filed against the Utility in connection with the 2019 Kincade fire and the 2020 Zogg fire. Under California law (including Penal Code section 1202.4), if the Utility were convicted of any of the charges, the sentencing court must order the Utility to “make restitution to the victim or victims in an amount established by court order” that is “sufficient to fully reimburse the victim or victims for every determined economic loss incurred as the result of” the Utility’s underlying conduct, in addition to interest and the victim’s or victims’ attorneys’ fees. This requirement for full reimbursement of economic loss is not waivable by either the government or the victims and is not offset by any compensation that the victims have received or may receive from their insurance carriers. If convicted of any of the charges, the Utility could be subject to fines, penalties, and restitution to victims for their economic losses (including property damage, medical and mental health expenses, lost wages, lost profits, attorneys’ fees and interest), as well as non-monetary remedies such as oversight requirements. In the event that the Utility were convicted of certain charges in connection with the 2019 Kincade fire or 2020 Zogg fire, the Utility currently believes that, depending on which charges it were to be convicted of, its total losses associated with such fire would materially exceed the accrued estimated liabilities that PG&E Corporation and the Utility have recorded to reflect the lower end of the range of the reasonably estimable range of losses. The Utility is currently unable to determine a reasonable estimate of the amount of such additional losses. The Utility does not expect that any of its liability insurance would be available to cover restitution payments ordered by the courts presiding over the criminal proceedings. PG&E Corporation and the Utility are aware of numerous civil complaints related to the following wildfire events and expect that they may receive further such complaints. The complaints include claims based on multiple theories of liability, including inverse condemnation, negligence, violations of the Public Utilities Code, violations of the Health & Safety Code, premises liability, trespass, public nuisance and private nuisance. The plaintiffs in each action principally assert that PG&E Corporation’s and the Utility’s alleged failure to properly maintain, inspect, and de-energize their transmission lines was the cause of the relevant wildfire. The timing and outcome for resolution of any such claims or investigations are uncertain. The Utility believes it will continue to receive additional information from potential claimants in connection with these wildfire events as litigation or resolution efforts progress. Any such additional information may potentially allow PG&E Corporation and the Utility to refine the estimates of their accrued losses and may result in changes to the accrual depending on the information received. PG&E Corporation and the Utility intend to vigorously defend themselves against both criminal charges and civil complaints. If the Utility’s facilities, such as its electric distribution and transmission lines, are judicially determined to be the substantial cause of the following matters, and the doctrine of inverse condemnation applies, the Utility could be liable for property damage, business interruption, interest and attorneys’ fees without having been found negligent. California courts have imposed liability under the doctrine of inverse condemnation in legal actions brought by property holders against utilities on the grounds that losses borne by the person whose property was damaged through a public use undertaking should be spread across the community that benefited from such undertaking, and based on the assumption that utilities have the ability to recover these costs through rates. Further, California courts have determined that the doctrine of inverse condemnation is applicable regardless of whether the CPUC ultimately allows recovery by the utility for any such costs. The CPUC may decide not to authorize cost recovery even if a court decision were to determine that the Utility is liable as a result of the application of the doctrine of inverse condemnation. In addition to claims for property damage, business interruption, interest and attorneys’ fees under inverse condemnation, PG&E Corporation and the Utility could be liable for fire suppression costs, evacuation costs, medical expenses, personal injury damages, punitive damages and other damages under other theories of liability in connection with the following wildfire events, including if PG&E Corporation or the Utility were found to have been negligent. PG&E Corporation and the Utility currently believe that it is reasonably possible that the amount of loss could be greater than the accrued estimated amounts but are unable to reasonably estimate the additional loss and the upper end of the range because, as described above, there are a number of unknown facts and legal considerations that may impact the amount of any potential liability, including the total scope and nature of claims that may be asserted against PG&E Corporation and the Utility and the outcome of the criminal proceedings initiated against the Utility. If the liability for wildfires were to exceed $1.0 billion in the aggregate in any Coverage Year, the Utility may be eligible to make a claim to the Wildfire Fund under AB 1054 to satisfy settled or finally adjudicated eligible claims in excess of such amount, except that claims related to the 2019 Kincade fire would be subject to the 40% limitation on the allowed amount of claims arising before emergence from bankruptcy. PG&E Corporation and the Utility intend to continue to review the available information and other information as it becomes available, including evidence in the possession of Cal Fire or the relevant district attorney’s office, evidence from or held by other parties, claims that have not yet been submitted, and additional information about the nature and extent of personal and business property damages and losses, the nature, number and severity of personal injuries, and information made available through the discovery process. 2019 Kincade Fire According to Cal Fire, on October 23, 2019 at approximately 9:27 p.m. Pacific Time, a wildfire began northeast of Geyserville in Sonoma County, California (the “2019 Kincade fire”), located in the service territory of the Utility. According to a Cal Fire incident update dated March 3, 2020, 3:35 p.m. Pacific Time, the 2019 Kincade fire consumed 77,758 acres and resulted in no fatalities, four first responder injuries, 374 structures destroyed, and 60 structures damaged. In connection with the 2019 Kincade fire, state and local officials issued numerous mandatory evacuation orders and evacuation warnings. Based on County of Sonoma information, PG&E Corporation and the Utility understand that the geographic zones subject to either a mandatory evacuation order or an evacuation warning between October 23, 2019 and November 4, 2019 included approximately 200,000 persons. On July 16, 2020, Cal Fire issued a press release with its determination that the Utility’s equipment caused the 2019 Kincade fire. On April 6, 2021, the Sonoma County District Attorney’s office filed the Kincade Complaint charging the Utility with five felonies and 28 misdemeanors related to the 2019 Kincade fire. On April 6, 2021, PG&E Corporation announced that it disputed the charges in the Kincade Complaint. It further announced that it would accept Cal Fire’s finding that a Utility transmission line caused the 2019 Kincade fire. On May 11, 2021, the Utility filed a demurrer to 25 of the 33 counts contained in the Kincade Complaint. At a hearing on September 9, 2021, the Sonoma County Superior Court overruled the demurrer. The Utility pled not guilty to all charges on October 13, 2021. On January 28, 2022, the Sonoma County District Attorney’s Office filed the Kincade Amended Complaint, which replaces two felonies with five different felonies and drops six misdemeanor counts. On January 28, 2022, the court deemed the Utility’s demurrer and the court’s prior ruling as applying to 22 of the 30 counts in the Kincade Amended Complaint, and the Utility thereafter pled not guilty to all charges in the Kincade Amended Complaint. A preliminary hearing on the charges began on February 8, 2022. On December 2, 2021, the CPUC approved a settlement between the Safety Enforcement Division and the Utility (the “Kincade SED Settlement”). The Kincade SED Settlement resolves SED’s investigation into the 2019 Kincade fire and provides for the removal of approximately 70 transmission lines or portions of lines that are no longer in service and are de-energized but have not been removed as required by CPUC rules. The Kincade SED Settlement provides that (i) the Utility will pay $40 million to California’s General Fund; (ii) the Utility will remove permanently abandoned transmission lines over a ten-year period; and (iii) the Utility must incur $85 million of the costs of such work by December 31, 2024, and it may not seek recovery of this $85 million of costs. SED agreed to refrain from instituting enforcement proceedings against the Utility for not having removed the lines previously. The Kincade SED Settlement states that it does not constitute an admission by the Utility of violations of GOs or statutory requirements. In connection with the Kincade SED Settlement, PG&E Corporation and the Utility recorded a liability of $40 million reflected in Other current liabilities on the Consolidated Financial Statements for the period ended December 31, 2021. For the $85 million of cost of removal that the Utility will not seek recovery, the Utility expects to record such disallowances in 2022. On January 10, 2022, TURN filed an application for rehearing of the Kincade SED Settlement. On January 25, 2022, the Utility filed an opposition to the application for rehearing. As of February 3, 2022, PG&E Corporation and the Utility are aware of approximately 100 complaints on behalf of at least 2,605 plaintiffs related to the 2019 Kincade fire. The plaintiffs filed master complaints on July 16, 2021; PG&E Corporation’s and the Utility’s response was filed on August 16, 2021; and PG&E Corporation and the Utility filed a demurrer with respect to the plaintiffs’ inverse condemnation claims. On December 10, 2021, the court overruled the demurrer. In addition, on January 5, 2022, Cal Fire filed a complaint in the coordinated proceeding seeking to recover approximately $90 million for fire suppression and other costs incurred in connection with the 2019 Kincade fire. Following a November 5, 2021 hearing, the San Francisco County Superior Court set a trial date of November 7, 2022. Based on the current state of the law concerning inverse condemnation in California and the facts and circumstances available to PG&E Corporation and the Utility as of the date of this filing, including Cal Fire’s determination of the cause and the information gathered as part of PG&E Corporation’s and the Utility’s investigation, PG&E Corporation and the Utility believe it is probable that they will incur a loss in connection with the 2019 Kincade fire. PG&E Corporation and the Utility recorded a liability in the aggregate amount of $625 million for the year ended December 31, 2020 (before available insurance). Based on the facts and circumstances available to the Utility as of the filing of PG&E Corporation’s and the Utility’s Consolidated Financial Statements for the year ended December 31, 2021, including the status of negotiations with certain subrogation entities, PG&E Corporation and the Utility recorded an additional charge in 2021 for potential losses in connection with the 2019 Kincade fire of $175 million, for an aggregate liability of $800 million (before available insurance). The Utility’s accrued estimated losses do not include, among other things: (i) any amounts for potential penalties, fines, or restitution that may be imposed by courts or other governmental entities on PG&E Corporation or the Utility, (ii) any punitive damages, (iii) any amounts in respect of compensation claims by federal or state agencies other than state fire suppression costs, (iv) evacuation costs, or (v) any other amounts that are not reasonably estimable. The following table presents changes in the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimable range of losses for claims arising from the 2019 Kincade fire since December 31, 2019. Loss Accrual (in millions) Balance at December 31, 2019 $ — Accrued Losses 625 Payments — Balance at December 31, 2020 625 Accrued Losses 175 Payments (31) Balance at December 31, 2021 $ 769 The Utility has liability insurance coverage for third-party liability attributable to the 2019 Kincade fire in an aggregate amount of $430 million. As of December 31, 2021, the Utility has recorded an insurance receivable for the full amount of the $430 million. 2020 Zogg Fire According to Cal Fire, on September 27, 2020, at approximately 4:03 p.m. Pacific Time, a wildfire began in the area of Zogg Mine Road and Jenny Bird Lane, north of Igo in Shasta County, California (the “2020 Zogg fire”), located in the service territory of the Utility. According to a Cal Fire incident update dated October 16, 2020, 3:08 p.m. Pacific Time, the 2020 Zogg fire consumed 56,338 acres and resulted in four fatalities, one injury, 204 structures destroyed, and 27 structures damaged. On March 22, 2021, Cal Fire issued a press release with its determination that the 2020 Zogg fire was caused by a pine tree contacting electrical facilities owned and operated by the Utility located north of the community of Igo. On September 24, 2021, the Shasta County District Attorney’s Office filed the Zogg Complaint charging the Utility with 11 felonies and 20 misdemeanors related to the 2020 Zogg fire, the 2020 Daniel fire, the 2020 Ponder fire, and the 2021 Woody fire. On September 24, 2021, PG&E Corporation and the Utility announced that they disputed the charges in the Zogg Complaint. They further announced that they would accept Cal Fire’s finding that a Utility electric line caused the 2020 Zogg fire, even though PG&E Corporation and the Utility did not have access to all of the evidence that Cal Fire gathered. On November 18, 2021, the Utility filed a demurrer to 10 of the 31 counts contained in the Zogg Complaint. A hearing on the demurrer is set for April 4, 2022. Various other entities, which may include other law enforcement agencies, may also be investigating the fire. It is uncertain when any such investigations will be complete. As of February 3, 2022, PG&E Corporation and the Utility are aware of approximately 21 complaints on behalf of at least 382 plaintiffs related to the 2020 Zogg fire. The plaintiffs seek damages that include wrongful death, property damage, economic loss, punitive damages, exemplary damages, attorneys’ fees and other damages. The plaintiffs filed master complaints on August 6, 2021, and PG&E Corporation’s and the Utility’s answer was filed on September 7, 2021, and PG&E Corporation and the Utility filed a demurrer with respect to the plaintiffs’ inverse condemnation claims. On December 10, 2021, the court overruled the demurrer. At an October 4, 2021 hearing, the San Francisco County Superior Court set a trial date of February 6, 2023. In addition, PG&E Corporation and the Utility have been contacted by Cal Fire to accept service of a complaint filed against them for fire suppression costs incurred in connection with the 2020 Zogg fire. Based on the current state of the law concerning inverse condemnation in California and the facts and circumstances available to PG&E Corporation and the Utility as of the date of this filing, including Cal Fire’s determination of the cause and the information gathered as part of PG&E Corporation’s and the Utility’s investigation, PG&E Corporation and the Utility believe it is probable that they will incur a loss in connection with the 2020 Zogg fire. PG&E Corporation and the Utility recorded a liability in the aggregate amount of $275 million for the year ended December 31, 2020 (before available insurance). Based on the facts and circumstances available to the Utility as of the filing of the Consolidated Financial Statements for the year ended December 31, 2021, including the status of negotiations with certain agencies, subrogation entities, and individual plaintiffs, PG&E Corporation and the Utility recorded an additional charge in 2021 for potential losses in connection with the 2020 Zogg fire in the amount of $100 million, for an aggregate liability of $375 million (before available insurance). Following continued negotiations during the quarter ended December 31, 2021, PG&E Corporation and the Utility entered agreements with all but one of the insurance subrogation plaintiffs in the 2020 Zogg fire litigation to resolve their claims arising from the 2020 Zogg fire. The Utility’s accrued estimated losses do not include, among other things: (i) any amounts for potential penalties, fines, or restitution that may be imposed by courts or other governmental entities on PG&E Corporation or the Utility, (ii) any punitive damages, (iii) any amounts in respect of compensation claims by federal or state agencies other than state fire suppression costs, (iv) evacuation costs, or (v) any other amounts that are not reasonably estimable. The following table presents changes in the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimable range of losses for claims arising from the 2020 Zogg fire since December 31, 2019. Loss Accrual (in millions) Balance at December 31, 2019 $ — Accrued Losses 275 Payments — Balance at December 31, 2020 275 Accrued Losses 100 Payments (164) Balance at December 31, 2021 $ 211 The Utility has liability insurance for third-party liability attributable to the 2020 Zogg fire in an aggregate amount of $611 million. This amount is reduced from the $867.5 million of coverage disclosed in the 2020 Form 10-K due to the Utility’s commuting certain insurance policies in connection with its April 2021 wildfire liability insurance renewal. As of December 31, 2021, the Utility has recorded an insurance receivable for $337 million for probable insurance recoveries in connection with the 2020 Zogg fire, which equals the $375 million probable loss estimate less an initial self-insured retention of $60 million, plus $22 million in legal fees incurred. Recovery under the Utility’s insurance policies for the 2021 Dixie fire will reduce the amount of insurance proceeds available for the 2020 Zogg fire by the same amount. 2021 Dixie Fire According to Cal Fire, on July 13, 2021, at approximately 5:15 p.m. Pacific Time, a wildfire began in the Feather River Canyon near Cresta Dam (the “2021 Dixie fire”), located in the service territory of the Utility. According to a Cal Fire incident update, dated October 25, 2021, 7:46 a.m. Pacific Time, the 2021 Dixie fire consumed 963,309 acres and resulted in 1,329 structures destroyed (including 717 residential, 143 commercial, and 443 other structures), 95 structures damaged, and one fatality, which according to published reports was a fire fighter who passed away due to COVID-19 after returning home from the 2021 Dixie fire. On January 4, 2022, Cal Fire issued a press release with its determination that the 2021 Dixie fire was caused by a tree contacting electrical distribution lines owned and operated by the Utility. The Butte County, Plumas County, Shasta County, Lassen County and Tehama County District Attorneys’ Offices, as well as the SED and OEIS, are investigating the fire; various other entities, which may include other state and federal law enforcement agencies, may also be investigating the fire. The United States Attorney’s Office for the Eastern District of California issued a subpoena for documents as well. PG&E Corporation and the Utility are cooperating with the investigations. It is uncertain when any such investigations will be complete. PG&E Corporation and the Utility are also conducting their own investigation into the cause of the 2021 Dixie fire. This investigation is ongoing, and PG&E Corporation and the Utility do not have access to all of the evidence in the possession of Cal Fire or other third parties. As of February 3, 2022, PG&E Corporation and the Utility are aware of approximately 20 complaints on behalf of at least 1,005 plaintiffs related to the 2021 Dixie fire and expect that they may receive further such complaints. The plaintiffs seek damages that include property damage, economic loss, punitive damages, exemplary damages, attorneys’ fees and other damages. Based on the current state of the law concerning inverse condemnation in California and the facts and circumstances available to PG&E Corporation and the Utility as of the date of this filing, including Cal Fire’s determination of the cause and the information gathered as part of PG&E Corporation’s and the Utility’s investigation, PG&E Corporation and the Utility believe it is probable that they will incur a loss in connection with the 2021 Dixie fire. PG&E Corporation and the Utility recorded a liability in the aggregate amount of $1.15 billion for the year ended December 31, 2021 (before available recoveries). The Utility’s accrued estimated losses do not include, among other things: (i) any amounts for potential penalties, fines, or restitution that may be imposed by courts or other governmental entities on PG&E Corporation or the Utility, (ii) any punitive damages, (iii) any amounts in respect of compensation claims by federal or state agencies including for state or federal fire suppression costs and damages related to federal land, (iv) evacuation costs, or (v) any other amounts that are not reasonably estimable. As noted above, the aggregate estimated liability for claims in connection with the 2021 Dixie fire does not include potential claims for fire suppression costs from federal, state, county, or local agencies or damage to land and vegetation in national parks or national forests. As to these damages, PG&E Corporation and the Utility have not concluded that a loss is probable due to the incomplete information available to PG&E Corporation and the Utility as of the date of this filing as to facts pertinent to potential claims and defenses. Moreover, PG&E Corporation and the Utility are currently unable to reasonably estimate the range of possible losses for any such claims due to, among other factors, incomplete information as to facts pertinent to potential claims and defenses, as well as facts that would bear on the amount, type, and valuation of vegetation loss, potential reforestation, habitat loss, and other resources damaged or destroyed by the 2021 Dixie fire. PG&E Corporation and the Utility believe, however, that such losses could be significant with respect to fire suppression costs due to the size and duration of the 2021 Dixie fire and corresponding magnitude of fire suppression resources dedicated to fighting the 2021 Dixie fire and with respect to claims for damage to land and vegetation in national parks or national forests due to the very large number of acres of national park and national forests that were affected by the 2021 Dixie fire. According to the National Interagency Coordination Center Incident Management Situation Report dated October 29, 2021 at 7:30 a.m. Mountain Time, over $630 million of costs had been incurred in suppressing the 2021 Dixie fire. The Utility currently estimates that the fire burned approximately 70,000 acres of national parks and approximately 685,000 acres of national forests. The Utility has liability insurance coverage for third-party liability attributable to periods in which both the 2020 Zogg fire and 2021 Dixie fire occurred in an aggregate amount of $900 million. Recovery under the Utility’s insurance policies for the 2020 Zogg fire will reduce the amount of insurance proceeds available for the 2021 Dixie fire by the same amount. An immaterial decrease was recorded in the fourth quarter of 2021. As of December 31, 2021, the Utility has recorded an insurance receivable of $563 million for probable insurance recoveries in connection with the 2021 Dixie fire, which equals the aggregate $900 million of available insurance coverage for third-party liability attributable to the 2021 Dixie fire, less the $337 million insurance receivable recorded in connection with the 2020 Zogg fire. As of December 31, 2021, the Utility has recorded a Wildfire Fund receivable of $150 million for probable recoveries in connection with the 2021 Dixie fire. See “Wildfire Fund under AB 1054” below. The Utility has also recorded a $101 million reduction to its regulatory liability for wildfire-related claims costs that were determined to be probable of recovery through the FERC TO formula rate and a $347 million regulatory asset for costs that were determined to be probable of recovery through the WEMA. See “Regulatory Recovery” below. Decreases in the amount of the insurance receivable for the 2021 Dixie fire may also increase the amount that is probable of recovery through the FERC TO formula rate and the WEMA. An immaterial increase was recorded in the fourth quarter of 2021. Loss Recoveries PG&E Corporation and the Utility have recovery mechanisms available for wildfire liabilities including from insurance, customers, and the Wildfire Fund. PG&E Corporation and the Utility record a receivable for a recovery when it is deemed probable that recovery of a recorded loss will occur, and the Utility can reasonably estimate the amount or its range. While the Utility plans to seek recovery of all insured losses, it is unable to predict the ultimate amount and timing of such insurance recoveries. Total probable recoveries for the 2021 Dixie fire as of December 31, 2021 are: Potential Recovery Source (in millions) 2021 Dixie fire Insurance $ 563 FERC TO rates 101 WEMA 347 Wildfire Fund 150 Probable recoveries at December 31, 2021 $ 1,161 The Utility could be subject to significant liability in connection with these wildfire events. If such liability is not recoverable from insurance or the other mechanisms described herein, it could have a material impact on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows. Insurance Coverage In April 2021, the Utility purchased approximately $268 million in wildfire liability insurance coverage for the period from April 13, 2021 to April 1, 2022, and approximately $32 million in incremental wildfire liability reinsurance for the period from April 1, 2021 to April 1, 2022 at a cost of approximately $220 million. This coverage is in addition to approximately $11 million in existing wildfire liability reinsurance for the period from July 1, 2020 to July 1, 2021 and approximately $600 million in existing wildfire liability insurance purchased by the Utility in August 2020 for the period from August 1, 2020 to August 1, 2021. On August 1, 2021, the $600 million of existing wildfire liability coverage renewed on a 12-month term covering the period from August 1, 2021 to August 1, 2022 at a cost of approximately $516 million pursuant to multi-year policy terms. The Utility’s wildfire liability insurance is subject to an initial self-insured retention of $60 million. In June 2021, the Utility purchased approximately $535 million in non-wildfire liability coverage for the period from June 1, 2021 to April 1, 2022 at a cost of approximately $89 million. This coverage is in addition to approximately $140 million in existing non-wildfire liability insurance for the period from August 1, 2020 to August 1, 2021. In connection with the June 2021 renewal, the Utility procured an extension of this existing coverage to April 1, 2022 at a premium cost of approximately $30 million. The Utility also has $50 million in additional non-wildfire liability coverage available through one of its wildfire liability policies with shared limits. The Utility’s non-wildfire liability insurance is subject to an initial self-insured retention of $10 million. As of December 31, 2021, PG&E Corporation and the Utility had prepaid insurance of $358 million, reflected in Other current assets on the Consolidated Balance Sheets. Various coverage limitations applicable to different insurance layers could result in material uninsured costs in the future depending on the amount and type of damages resulting from covered events. In the Utility’s 2020 GRC proceeding, the CPUC also approved a settlement agreement provision that allows the Utility to recover annual insurance costs for up to $1.4 billion in general liability insurance coverage. For more information about the RTBA, see Note 4 above. Insurance Receivable Through December 31, 2021, PG&E Corporation and the Utility recorded $430 million for probable insurance recoveries in connection with the 2019 Kincade fire, $337 million for probable insurance recoveries in connection with the 2020 Zogg fire, and $563 million for probable insurance recoveries in connection with the 2021 Dixie fire. PG&E Corporation and the Utility intend to seek full recovery for all insured losses. The balances for insurance receivables with respect to wildfires are included in Other accounts receivable in PG&E Corporation’s and the Utility’s Consolidated Balance Sheets: Insurance Receivable (in millions) 2021 Dixie fire 2020 Zogg fire 2019 Kincade fire 2018 Camp fire 2017 Northern California wildfires 2015 Butte fire Total Balance at December 31, 2019 $ — $ — $ — $ 1,380 $ 808 $ 50 $ 2,238 Accrued insurance recoveries — 219 430 — — — 649 R

SCHEDULE I _ CONDENSED FINANCIA

SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT	12 Months Ended
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT	Dec. 31, 2021
Condensed Financial Information Disclosure [Abstract]
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT	PG&E CORPORATION SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF PARENT CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME Years Ended December 31, (in millions, except per share amounts) 2021 2020 2019 Administrative service revenue $ 118 $ 127 $ 138 Operating expenses (124) (103) (114) Interest income — — 1 Interest expense (230) (149) (21) Other income (expense) (54) 13 10 Reorganization items, net 1 (1,649) (26) Equity in earnings of subsidiaries 137 411 (7,622) Loss before income taxes (152) (1,350) (7,634) Income tax provision (benefit) (64) (46) 8 Net loss $ (88) $ (1,304) $ (7,642) Other Comprehensive Income (Loss) Pension and other postretirement benefit plans obligations (net of taxes of $3, $7, and $0, at respective dates) $ 7 $ (17) $ (1) Total other comprehensive income (loss) 7 (17) (1) Comprehensive Loss $ (81) $ (1,321) $ (7,643) Weighted Average Common Shares Outstanding, Basic (1) 2,463 1,257 528 Weighted Average Common Shares Outstanding, Diluted (1) 2,463 1,257 528 Net loss per common share, basic $ (0.05) $ (1.05) $ (14.50) Net loss per common share, diluted $ (0.05) $ (1.05) $ (14.50) (1) Includes 477,743,590 shares of common stock issued to ShareCo. PG&E CORPORATION SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF PARENT – (Continued) CONDENSED BALANCE SHEETS Balance at December 31, (in millions) 2021 2020 ASSETS Current Assets Cash and cash equivalents $ 126 $ 223 Advances to affiliates 21 48 Income taxes receivable 10 12 Other current assets 12 13 Total current assets 169 296 Noncurrent Assets Equipment 2 2 Accumulated depreciation (2) (2) Net equipment — — Investments in subsidiaries 30,232 25,244 Other investments 181 186 Operating lease right of use asset — 3 Deferred income taxes 297 237 Total noncurrent assets 30,710 25,670 Total Assets $ 30,879 $ 25,966 LIABILITIES AND SHAREHOLDERS’ EQUITY Current Liabilities Long-term debt, classified as current 27 28 Accounts payable – other 200 49 Operating lease liabilities — 3 Other current liabilities 69 72 Total current liabilities 296 152 Noncurrent Liabilities Debtor-in-possession financing 4,592 4,624 Operating lease liabilities — — Other noncurrent liabilities 168 191 Total noncurrent liabilities 4,760 4,815 Common Shareholders’ Equity Common stock 35,129 30,224 Reinvested earnings (9,286) (9,198) Accumulated other comprehensive loss (20) (27) Total common shareholders’ equity 25,823 20,999 Total Liabilities and Shareholders’ Equity $ 30,879 $ 25,966 PG&E CORPORATION SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT – (Continued) CONDENSED STATEMENTS OF CASH FLOWS (in millions) Year ended December 31, 2021 2020 2019 Cash Flows from Operating Activities: Net loss $ (88) $ (1,304) $ (7,642) Adjustments to reconcile net income to net cash provided by operating activities: Stock-based compensation amortization 51 28 43 Equity in earnings (loss) of subsidiaries (139) (412) 7,622 Deferred income taxes and tax credits-net (60) (50) — Reorganization items, net (Note 2) (32) 1,548 11 Current income taxes receivable/payable 2 — 6 Liabilities subject to compromise — 12 28 Other 81 97 (62) Net cash provided by (used in) operating activities (185) (81) 6 Cash Flows From Investing Activities: Investment in subsidiaries — (12,986) — Net cash used in investing activities — (12,986) — Cash Flows From Financing Activities: Debtor-in-possession credit facility debt issuance costs — — (16) Bridge facility financing fees — (40) — Proceeds from issuance of long-term debt — 4,660 — Repayment of long-term debt (28) (664) — Intercompany note from the Utility 145 — — Common stock issued — 7,582 85 Equity Units issued — 1,304 — Other (29) — — Net cash provided by financing activities 88 12,842 69 Net change in cash and cash equivalents (97) (225) 75 Cash and cash equivalents at January 1 223 448 373 Cash and cash equivalents at December 31 $ 126 $ 223 $ 448 Supplemental disclosures of cash flow information Cash received (paid) for: Interest, net of amounts capitalized $ (207) $ (105) $ (3) Income taxes, net 1 — — Supplemental disclosures of noncash investing and financing activities Operating lease liabilities arising from obtaining ROU assets $ — $ — $ 9 Common stock issued in satisfaction of liabilities — 8,276 — Increase to PG&E Corporation common stock and treasury stock in connection 4,854 — —

SCHEDULE II _ CONSOLIDATED VALU

SCHEDULE II – CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS	12 Months Ended
	Dec. 31, 2021
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
SCHEDULE II – CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS	PG&E CORPORATION SCHEDULE II – CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2021, 2020, and 2019 (in millions) Additions Description Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts Deductions (2) Balance at End of Period Valuation and qualifying accounts deducted from assets: 2021: Allowance for uncollectible accounts (1) $ 146 $ 136 $ — $ 111 $ 171 2020: Allowance for uncollectible accounts (1) $ 43 $ 138 $ — $ 35 $ 146 2019: Allowance for uncollectible accounts (1) $ 56 $ — $ — $ 13 $ 43 (1) Allowance for uncollectible accounts is deducted from “Accounts receivable - Customers.” (2) Deductions consist principally of write-offs, net of collections of receivables previously written off. PACIFIC GAS AND ELECTRIC COMPANY SCHEDULE II – CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2021, 2020, and 2019 (in millions) Additions Description Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts Deductions (2) Balance at End of Period Valuation and qualifying accounts deducted from assets: 2021: Allowance for uncollectible accounts (1) $ 146 $ 136 $ — $ 111 $ 171 2020: Allowance for uncollectible accounts (1) $ 43 $ 138 $ — $ 35 $ 146 2019: Allowance for uncollectible accounts (1) $ 56 $ — $ — $ 13 $ 43 (1) Allowance for uncollectible accounts is deducted from “Accounts receivable - Customers.” (2) Deductions consist principally of write-offs, net of collections of receivables previously written off.

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	Dec. 31, 2021
Accounting Policies [Abstract]
Basis of Presentation	This is a combined annual report of PG&E Corporation and the Utility. PG&E Corporation’s Consolidated Financial Statements include the accounts of PG&E Corporation, the Utility, and other wholly owned and controlled subsidiaries. The Utility’s Consolidated Financial Statements include the accounts of the Utility and its wholly owned and controlled subsidiaries. All intercompany transactions have been eliminated in consolidation. The Notes to the Consolidated Financial Statements apply to both PG&E Corporation and the Utility. PG&E Corporation and the Utility assess financial performance and allocate resources on a consolidated basis (i.e., the companies operate in one segment).
Use of Estimates and Assumptions	The preparation of financial statements in conformity with GAAP requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Some of the more significant estimates and assumptions relate to the Utility’s regulatory assets and liabilities, wildfire-related liabilities, legal and regulatory contingencies, the Wildfire Fund, environmental remediation liabilities, AROs, wildfire-related receivables, and pension and other post-retirement benefit plan obligations. Management believes that its estimates and assumptions reflected in the Consolidated Financial Statements are appropriate and reasonable. A change in management’s estimates or assumptions could result in an adjustment that would have a material impact on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows during the period in which such change occurred.
Regulation and Regulated Operations	The Utility follows accounting principles for rate-regulated entities and collects rates from customers to recover “revenue requirements” that have been authorized by the CPUC or the FERC based on the Utility’s cost of providing service. The Utility’s ability to recover a significant portion of its authorized revenue requirements through rates is generally independent, or “decoupled,” from the volume of the Utility’s electricity and natural gas sales. The Utility records assets and liabilities that result from the regulated ratemaking process that would not be recorded under GAAP for nonregulated entities. The Utility capitalizes and records, as regulatory assets, costs that would otherwise be charged to expense if it is probable that the incurred costs will be recovered through future rates. Regulatory assets are amortized over the future periods in which the costs are recovered. If costs expected to be incurred in the future are currently being recovered through rates, the Utility records those expected future costs as regulatory liabilities. Amounts that are probable of being credited or refunded to customers in the future are also recorded as regulatory liabilities. The Utility also records a regulatory balancing account asset or liability for differences between customer billings and authorized revenue requirements that are probable of recovery or refund. In addition, the Utility records a regulatory balancing account asset or liability for differences between incurred costs and customer billings or authorized revenue meant to recover those costs, to the extent that these differences are probable of recovery or refund. These differences have no impact on net income. See “Revenue Recognition” below. Management continues to believe the use of regulatory accounting is applicable and that all regulatory assets and liabilities are recoverable or refundable. To the extent that portions of the Utility’s operations cease to be subject to cost of service rate regulation, or recovery is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are written off.
Cash, Cash Equivalents and Restricted Cash	Cash and cash equivalents consist of cash and short-term, highly liquid investments with original maturities of three months or less. Cash equivalents are stated at fair value. As of December 31, 2020, the Utility also held restricted cash that primarily consisted of cash held in escrow to be used to pay bankruptcy related professional fees.
Revenue Recognition	Revenue from Contracts with Customers The Utility recognizes revenues when electricity and natural gas services are delivered. The Utility records unbilled revenues for the estimated amount of energy delivered to customers but not yet billed at the end of the period. Unbilled revenues are included in accounts receivable on the Consolidated Balance Sheets. Rates charged to customers are based on CPUC and FERC authorized revenue requirements. Revenues can vary significantly from period to period because of seasonality, weather, and customer usage patterns. Regulatory Balancing Account Revenue The CPUC authorizes most of the Utility’s revenues in the Utility’s GRCs, which occur every four years. The Utility's ability to recover revenue requirements authorized by the CPUC in these rate cases is independent or “decoupled” from the volume of the Utility's sales of electricity and natural gas services. The Utility recognizes revenues that have been authorized for rate recovery, are objectively determinable and probable of recovery, and are expected to be collected within 24 months. Generally, electric and natural gas operating revenue is recognized ratably over the year. The Utility records a balancing account asset or liability for differences between customer billings and authorized revenue requirements that are probable of recovery or refund. The Utility also collects additional revenue requirements to recover costs that the CPUC has authorized the Utility to pass on to customers, including costs to purchase electricity and natural gas, and to fund public purpose, demand response, and customer energy efficiency programs. In general, the revenue recognition criteria for pass-through costs billed to customers are met at the time the costs are incurred. The Utility records a regulatory balancing account asset or liability for differences between incurred costs and customer billings or authorized revenue meant to recover those costs, to the extent that these differences are probable of recovery or refund. As a result, these differences have no impact on net income.
Allowance for Doubtful Accounts Receivable and Credit Losses	Financial Assets Measured at Amortized Cost – Credit Losses PG&E Corporation and the Utility use the current expected credit loss model to estimate the expected lifetime credit loss on financial assets measured at amortized cost. PG&E Corporation and the Utility evaluate credit risk in their portfolio of financial assets quarterly. As of December 31, 2021, PG&E Corporation and the Utility have identified the following significant categories of financial assets. Trade Receivables Trade receivables are represented by customer accounts. PG&E Corporation and the Utility record an allowance for doubtful accounts to recognize an estimate of expected lifetime credit losses. The allowance is determined on a collective basis based on the historical amounts written-off and an assessment of customer collectability. Furthermore, economic conditions are evaluated as part of the estimate of expected lifetime credit losses using an analysis of regional unemployment rates. As of December 31, 2021, the allowance also included the estimated impact of the CAPP which offers financial assistance from the State of California for eligible customers in the form of a credit to the customer’s bill. The Utility recorded a reduction to the allowance for doubtful accounts of approximately $207 million in the fourth quarter of 2021 as a result of the expected CAPP funding, which was received on January 27, 2022. As of December 31, 2021, the Utility recorded $209 million of long-term accounts receivables as a result of the CPUC’s June 30, 2021 final decision on bill debt relief which offers financial assistance for eligible customers in the form of a 24-month payment plan. As of December 31, 2021, expected credit losses of $154 million were recorded in Operating and maintenance expense on the Consolidated Statements of Income for credit losses associated with trade and other receivables. The portion of expected credit losses that are deemed probable of recovery are deferred to the RUBA, CPPMA and a FERC regulatory asset. At December 31, 2021, the RUBA current balancing accounts receivable balance was $127 million, and CPPMA and FERC long-term regulatory asset balances were $30 million and $12 million, respectively. Other Receivables and Available-For-Sale Debt Securities Insurance receivables are related to the liability insurance policies PG&E Corporation and the Utility carry. Insurance receivable risk is related to each insurance carrier’s risk of defaulting on their individual policies. Wildfire fund receivables are the funds available from the statewide fund established under AB 1054 for payment of eligible claims related to the 2021 Dixie fire that exceed $1.0 billion and available insurance coverage. For more information, see Note 14 below. Wildfire fund receivables risk is related to the Wildfire Fund’s durability, which is a measurement of the claim-paying capacity. Lastly, PG&E Corporation and the Utility are required to determine if the fair value is below the amortized cost basis for its available-for-sale debt securities. An impairment may exist if there is an intent to sell or a requirement to sell before recovery of the amortized basis. If such an impairment exists, then PG&E Corporation and the Utility must determine whether a portion of the impairment is a result of expected credit loss. As of December 31, 2021, expected credit losses for insurance receivables, Wildfire Fund receivables, and available-for-sale debt securities were immaterial.
Inventories	Inventories are carried at weighted-average cost and include natural gas stored underground as well as materials and supplies. Natural gas stored underground is recorded to inventory when injected and then expensed as the gas is withdrawn for distribution to customers or to be used as fuel for electric generation. Materials and supplies are recorded to inventory when purchased and expensed or capitalized to plant, as appropriate, when consumed or installed.
Emission Allowances	The Utility purchases GHG emission allowances to satisfy its compliance obligations. Associated costs are recorded as inventory and included in current assets – other and other noncurrent assets – other on the Consolidated Balance Sheets. Costs are carried at weighted-average and are recoverable through rates.
Property, Plant, And Equipment	Property, plant, and equipment are reported at the lower of their historical cost less accumulated depreciation or fair value. Historical costs include labor and materials, construction overhead, and AFUDC. See “AFUDC” below. The Utility depreciates property, plant, and equipment using the composite, or group, method of depreciation, in which a single depreciation rate is applied to the gross investment balance in a particular class of property, with the exception of its securitized property, plant and equipment, which is depreciated over the life of the bond and a pattern consistent with principal payments. This method approximates the straight-line method of depreciation over the useful lives of property, plant, and equipment. The Utility’s composite depreciation rates were 3.82% in 2021, 3.76% in 2020, and 3.80% in 2019. The useful lives of the Utility’s property, plant, and equipment are authorized by the CPUC and the FERC, and the depreciation expense is recovered through rates charged to customers. Depreciation expense includes a component for the original cost of assets and a component for estimated cost of future removal, net of any salvage value at retirement. Upon retirement, the original cost of the retired assets, net of salvage value, is charged against accumulated depreciation. The cost of repairs and maintenance, including planned major maintenance activities and minor replacements of property, is charged to operating and maintenance expense as incurred.
AFUDC	AFUDC represents the estimated costs of debt (i.e., interest) and equity funds used to finance regulated plant additions before they go into service and is capitalized as part of the cost of construction. AFUDC is recoverable through rates over the life of the related property once the property is placed in service. AFUDC related to the cost of debt is recorded as a reduction to interest expense. AFUDC related to the cost of equity is recorded in other income.
Nuclear Decommissioning Obligation	Nuclear Decommissioning Obligation Detailed studies of the cost to decommission the Utility’s nuclear generation facilities are generally conducted every three years in conjunction with the Nuclear Decommissioning Cost Triennial Proceeding. In December 2021, the Utility submitted its updated decommissioning cost estimate to the CPUC and correspondingly decreased its ARO liabilities by $1.4 billion. The adjustment was a result of a decrease in estimated costs based on refinements to the site-specific decommissioning analysis. The decommissioning cost estimates are based on the plant location and cost characteristics for the Utility's nuclear power plants. Actual decommissioning costs may vary from these estimates as a result of changes in assumptions such as decommissioning dates; regulatory requirements; technology; and costs of labor, materials, and equipment. The Utility recovers its revenue requirements for decommissioning costs through rates through a non-bypassable charge that the Utility expects will continue until those costs are fully recovered.
Disallowance of Plant Costs	PG&E Corporation and the Utility record a charge when it is both probable that costs incurred or projected to be incurred for recently completed plant will not be recoverable through rates charged to customers and the amount of disallowance can be reasonably estimated.
Nuclear Decommissioning Trusts	The Utility’s nuclear generation facilities consist of two units at Diablo Canyon and one retired facility at Humboldt Bay. Nuclear decommissioning requires the safe removal of a nuclear generation facility from service and the reduction of residual radioactivity to a level that permits termination of the NRC license and release of the property for unrestricted use. The Utility's nuclear decommissioning costs are recovered through rates and are held in trusts until authorized for release by the CPUC. The Utility classifies its debt investments held in the nuclear decommissioning trusts as available-for-sale. Since the Utility’s nuclear decommissioning trust assets are managed by external investment managers, the Utility does not have the ability to sell its investments at its discretion. Therefore, all unrealized losses are considered other-than-temporary impairments. Gains or losses on the nuclear decommissioning trust investments are refundable or recoverable, respectively, from customers through rates. Therefore, trust earnings are deferred and included in the regulatory liability for recoveries in excess of the ARO. There is no impact on the Utility’s earnings or accumulated other comprehensive income. The cost of debt and equity securities sold by the trust is determined by specific identification.
Variable Interest Entities	A VIE is an entity that does not have sufficient equity at risk to finance its activities without additional subordinated financial support from other parties, or whose equity investors lack any characteristics of a controlling financial interest. An enterprise that has a controlling financial interest in a VIE is a primary beneficiary and is required to consolidate the VIE. Consolidated VIEs Receivables Securitization Program The SPV created in connection with the Receivables Securitization Program (as defined below in Note 5 below) in October 2020 is a bankruptcy remote, limited liability company wholly owned by the Utility, and its assets are not available to creditors of PG&E Corporation or the Utility. Pursuant to the Receivables Securitization Program, the Utility sells certain of its receivables and certain related rights to payment and obligations of the Utility with respect to such receivables, and certain other related rights to the SPV, which, in turn, obtains loans secured by the receivables from financial institutions (the “Lenders”). Amounts received from the Lenders, the pledged receivables and the corresponding debt are included in Accounts receivable, Other noncurrent assets, and Long-term debt, respectively, on the Consolidated Balance Sheets. As of December 31, 2021, the aggregate principal amount of the loans made by the Lenders cannot exceed $1.0 billion outstanding at any time. On September 15, 2021, the Receivables Securitization Program was amended and extended to September 15, 2023. The SPV is considered a VIE because its equity capitalization is insufficient to support its activities. The most significant activities that impact the economic performance of the SPV are decisions made to manage receivables. The Utility is considered the primary beneficiary and consolidates the SPV as it makes these decisions. No additional financial support was provided to the SPV during the year ended December 31, 2021 or is expected to be provided in the future that was not previously contractually required. As of December 31, 2021 and 2020, the SPV had net accounts receivable of $3.3 billion and $2.6 billion, respectively, and outstanding borrowings of $974 million and $1.0 billion, respectively, under the Receivables Securitization Program. AB 1054 Securitization PG&E Recovery Funding LLC is a bankruptcy remote, limited liability company wholly owned by the Utility, and its assets are not available to creditors of PG&E Corporation or the Utility. Pursuant to the Financing Order for AB 1054, the Utility sold its right to receive revenues from the non-bypassable wildfire hardening fixed recovery charge (“Recovery Property”) to PG&E Recovery Funding LLC, which, in turn, issued recovery bonds secured by the Recovery Property. On November 12, 2021, PG&E Recovery Funding LLC issued approximately $860 million of senior secured recovery bonds. The recovery bonds were issued in three tranches: (1) approximately $266 million with an interest rate of 1.46% and is due July 15, 2033, (2) approximately $160 million with an interest rate of 2.28% and is due January 15, 2038, and (3) approximately $434 million with an interest rate of 2.82% and is due July 15, 2048. The recovery bonds are scheduled to pay principal and interest semi-annually on January 15 and July 15 of each year. The final scheduled payment date is July 15, 2046. Amounts owed to bond-holders are included in Long-term debt and Long-term debt, classified as current, on the Consolidated Balance Sheets. PG&E Recovery Funding LLC is considered a VIE because its equity capitalization is insufficient to support its operations. The most significant activities that impact the economic performance of PG&E Recovery Funding LLC are decisions made by the servicer of the Recovery Property. The Utility is considered the primary beneficiary and consolidates PG&E Recovery Funding LLC as it acts in this role as servicer. No additional financial support was provided to PG&E Recovery Funding LLC during the year ended December 31, 2021 or is expected to be provided in the future that was not previously contractually required. As of December 31, 2021, PG&E Recovery Funding LLC has outstanding borrowings of $860 million. Non-Consolidated VIEs Some of the counterparties to the Utility’s power purchase agreements are considered VIEs. Each of these VIEs was designed to own a power plant that would generate electricity for sale to the Utility. To determine whether the Utility was the primary beneficiary of any of these VIEs at December 31, 2021, it assessed whether it absorbs any of the VIE’s expected losses or receives any portion of the VIE’s expected residual returns under the terms of the power purchase agreement, analyzed the variability in the VIE’s gross margin, and considered whether it had any decision-making rights associated with the activities that are most significant to the VIE’s performance, such as dispatch rights and operating and maintenance activities. The Utility’s financial obligation is limited to the amount the Utility pays for delivered electricity and capacity. The Utility did not have any decision-making rights associated with any of the activities that are most significant to the economic performance of any of these VIEs. Since the Utility was not the primary beneficiary of any of these VIEs at December 31, 2021, it did not consolidate any of them.
Recognition of Lease Assets and Liabilities	A lease exists when an arrangement allows the lessee to control the use of an identified asset for a stated period in exchange for payments. This determination is made at inception of the arrangement. All leases must be recognized as a ROU asset and a lease liability on the balance sheet of the lessee. The ROU asset reflects the lessee’s right to use the underlying asset for the lease term and the lease liability reflects the obligation to make the lease payments. PG&E Corporation and the Utility have elected not to separate lease and non-lease components. The Utility estimates the ROU assets and lease liabilities at net present value using its incremental secured borrowing rates, unless the implicit discount rate in the leasing arrangement can be ascertained. The incremental secured borrowing rate is based on observed market data and other information available at the lease commencement date. The ROU assets and lease liabilities only include the fixed lease payments for arrangements with terms greater than 12 months. These amounts are presented within the supplemental disclosures of noncash activities on the Consolidated Statement of Cash Flows. Renewal and termination options only impact the lease term if it is reasonably certain that they will be exercised. PG&E Corporation recognizes lease expense on a straight-line basis over the lease term. The Utility recognizes lease expense in conformity with ratemaking.
Recently Adopted Accounting Standards and Accounting Standards Issued But Not Yet Adopted	Income Taxes In December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes , which amends the existing guidance to reduce complexity relating to Income Tax disclosures. PG&E Corporation and the Utility adopted this ASU on January 1, 2021. There was no material impact on PG&E Corporation’s or the Utility’s Consolidated Financial Statements and the related disclosures resulting from the adoption of this ASU. Government Assistance In November 2021, the FASB issued ASU No. 2021-10, Government Assistance (Topic 832): Disclosures by Business Entities about Government Assistance , which increases the transparency of government assistance including the disclosure of (1) the types of assistance, (2) an entity’s accounting for the assistance, and (3) the effect of the assistance on an entity’s financial statements. PG&E Corporation and the Utility adopted this ASU as of December 31, 2021. There was no material impact on PG&E Corporation’s or the Utility’s Consolidated Financial Statements and the related disclosures resulting from the adoption of this ASU. In August 2020, the FASB issued ASU No. 2020-06, Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging - Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity
Earnings Per Share	PG&E Corporation’s basic EPS is calculated by dividing the income (loss) available for common shareholders by the weighted average number of common shares outstanding. PG&E Corporation applies the treasury stock method of reflecting the dilutive effect of outstanding share-based compensation in the calculation of diluted EPS.
Fair Value Measurement	PG&E Corporation and the Utility measure their cash equivalents, trust assets, and price risk management instruments at fair value. A three-tier fair value hierarchy is established that prioritizes the inputs to valuation methodologies used to measure fair value: • Level 1 – Observable inputs that reflect quoted prices (unadjusted) for identical assets or liabilities in active markets. • Level 2 – Other inputs that are directly or indirectly observable in the marketplace. • Level 3 – Unobservable inputs which are supported by little or no market activities. The fair value hierarchy requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value.

BANKRUPTCY FILING (Tables)

BANKRUPTCY FILING (Tables)	12 Months Ended
BANKRUPTCY FILING (Tables)	Dec. 31, 2021
Reorganizations [Abstract]
Schedule of Debtor Reorganization Items	Reorganization items, net for the year ended December 31, 2021 include the following: Year Ended December 31, 2021 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ — $ — $ — Legal and other 21 (1) 20 Interest and other (9) — (9) Total reorganization items, net $ 12 $ (1) $ 11 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. Reorganization items, net for the year ended December 31, 2020 include the following: Year Ended December 31, 2020 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 6 $ — $ 6 Legal and other (2) 318 1,651 1,969 Interest income (14) (2) (16) Total reorganization items, net $ 310 $ 1,649 $ 1,959 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) Amount includes $1.5 billion in equity backstop premium expense and bridge loan facility fees. Reorganization items, net from the Petition Date through December 31, 2019 include the following: Petition Date Through December 31, 2019 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 97 $ 17 $ 114 Legal and other 273 19 292 Interest income (50) (10) (60) Total reorganization items, net $ 320 $ 26 $ 346 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility.

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	Dec. 31, 2021
Accounting Policies [Abstract]
Summary of Revenues Disaggregated by Type of Customer	The following table presents the Utility’s revenues disaggregated by type of customer: Year Ended (in millions) 2021 2020 Electric Revenue from contracts with customers Residential $ 6,089 $ 5,523 Commercial 5,042 4,722 Industrial 1,493 1,530 Agricultural 1,565 1,471 Public street and highway lighting 73 69 Other (1) (84) (130) Total revenue from contracts with customers - electric 14,178 13,185 Regulatory balancing accounts (2) 953 673 Total electric operating revenue $ 15,131 $ 13,858 Natural gas Revenue from contracts with customers Residential $ 2,759 $ 2,517 Commercial 713 597 Transportation service only 1,346 1,211 Other (1) 140 61 Total revenue from contracts with customers - gas 4,958 4,386 Regulatory balancing accounts (2) 553 225 Total natural gas operating revenue 5,511 4,611 Total operating revenues $ 20,642 $ 18,469 (1) This activity is primarily related to the change in unbilled revenue and amounts subject to refund, partially offset by other miscellaneous revenue items. (2) These amounts represent revenues authorized to be billed or refunded to customers.
Schedule of Estimated Useful Lives and Balances of Utility's Property, Plant and Equipment	The Utility’s estimated service lives of its property, plant, and equipment were as follows: Estimated Service Balance at December 31, (in millions, except estimated service lives) Lives (years) 2021 2020 Electricity generating facilities (1) 5 to 75 $ 11,217 $ 12,505 Electricity distribution facilities 10 to 70 37,723 34,902 Electricity transmission facilities 15 to 75 15,516 14,414 Natural gas distribution facilities 20 to 60 14,100 12,962 Natural gas transmission and storage facilities 5 to 66 9,067 8,293 Financing lease 18 18 Construction work in progress 3,480 2,757 General plant and other 5 to 50 7,838 8,041 Total property, plant, and equipment 98,959 93,892 Accumulated depreciation (29,131) (27,756) Net property, plant, and equipment (2) $ 69,828 $ 66,136 (1) Balance includes nuclear fuel inventories. Stored nuclear fuel inventory is stated at weighted-average cost. Nuclear fuel in the reactor is expensed as it is used based on the amount of energy output. See Note 15 below. (2) Includes $850 million of fire risk mitigation-related property, plant, and equipment securitized in accordance with AB 1054. See Note 5 below.
Schedule of Changes in Asset Retirement Obligations	The following table summarizes the changes in ARO liability during 2021 and 2020, including nuclear decommissioning obligations: (in millions) 2021 2020 ARO liability at beginning of year $ 6,412 $ 5,854 Liabilities incurred in the current period — 268 Revision in estimated cash flows (1,378) 53 Accretion 287 265 Liabilities settled (23) (28) ARO liability at end of year $ 5,298 $ 6,412
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income	The changes, net of income tax, in PG&E Corporation’s accumulated other comprehensive income (loss) for the year ended December 31, 2021 consisted of the following: (in millions, net of income tax) Pension Other Total Beginning balance $ (39) $ 17 $ (22) Other comprehensive income before reclassifications: Unrecognized net actuarial gain (net of taxes of $391 and $53, respectively) 1,007 137 1,144 Regulatory account transfer (net of taxes of $390 and $53, respectively) (1,003) (136) (1,139) Amounts reclassified from other comprehensive income: Amortization of prior service cost (net of taxes of $2 and $4, respectively) (1) (4) 10 6 Amortization of net actuarial (gain) loss (net of taxes of $2 and $9, respectively) (1) 4 (24) (20) Regulatory account transfer (net of taxes of $1 and $5, respectively) (1) 2 14 16 Net current period other comprehensive income 6 1 7 Ending balance $ (33) $ 18 $ (15) (1) These components are included in the computation of net periodic pension and other postretirement benefit costs. See Note 12 below for additional details. The changes, net of income tax, in PG&E Corporation’s accumulated other comprehensive income (loss) for the year ended December 31, 2020 consisted of the following: (in millions, net of income tax) Pension Other Total Beginning balance $ (22) $ 17 $ (5) Other comprehensive income before reclassifications: Unrecognized net actuarial gain (loss) (net of taxes of $162 and $66, respectively) (417) 170 (247) Regulatory account transfer (net of taxes of $155 and $66, respectively) 400 (170) 230 Amounts reclassified from other comprehensive income: Amortization of prior service cost (net of taxes of $2 and $4, respectively) (1) (4) 10 6 Amortization of net actuarial (gain) loss (net of taxes of $1 and $6, respectively) (1) 2 (15) (13) Regulatory account transfer (net of taxes of $1 and $2, respectively) (1) 2 5 7 Net current period other comprehensive loss (17) — (17) Ending balance $ (39) $ 17 $ (22) (1) These components are included in the computation of net periodic pension and other postretirement benefit costs. See Note 12 below for additional details.
Schedule of Lease Expense	The following table shows the lease expense recognized for the fixed and variable component of the Utility’s lease obligations: Year Ended December 31, (in millions) 2021 2020 Operating lease fixed cost $ 578 $ 679 Operating lease variable cost 1,782 1,852 Total operating lease costs $ 2,360 $ 2,531
Schedule of Future Expected Operating Lease Payments	At December 31, 2021, the Utility’s future expected operating lease payments were as follows: (in millions) December 31, 2021 2022 $ 533 2023 276 2024 118 2025 111 2026 105 Thereafter 444 Total lease payments 1,587 Less imputed interest (310) Total $ 1,277

REGULATORY ASSETS, LIABILITIE_2

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Tables)	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Abstract]
Long-Term Regulatory Assets	Long-term regulatory assets are comprised of the following: Balance at December 31, Recovery (in millions) 2021 2020 Pension benefits (1) $ 708 $ 2,245 Indefinitely Environmental compliance costs 1,089 1,112 32 years Utility retained generation (2) 133 181 6 years Price risk management 216 204 19 years Unamortized loss, net of gain, on reacquired debt 37 49 23 years Catastrophic event memorandum account (3) 1,119 842 1 - 3 years Wildfire expense memorandum account (4) 347 400 TBD years Fire hazard prevention memorandum account (5) 75 137 1 - 3 years Fire risk mitigation memorandum account (6) 44 66 1 - 3 years Wildfire mitigation plan memorandum account (7) 424 390 1 - 3 years Deferred income taxes (8) 1,849 908 51 years Insurance premium costs (9) 207 294 3 - 4 years Wildfire mitigation balancing account (10) 273 156 1 - 3 years General rate case memorandum accounts (11) — 376 1 - 2 years Vegetation management balancing account (12) 1,411 592 1 - 3 years COVID-19 pandemic protection memorandum accounts (13) 49 84 TBD years Other 1,226 942 Various Total long-term regulatory assets $ 9,207 $ 8,978 (1) Payments into the pension and other benefits plans are based on annual contribution requirements. As these annual requirements continue indefinitely into the future, the Utility expects to continuously recover pension benefits. (2) In connection with the settlement agreement entered into among PG&E Corporation, the Utility, and the CPUC in 2003 to resolve the Utility’s 2001 proceeding under Chapter 11, the CPUC authorized the Utility to recover $1.2 billion of costs related to the Utility’s retained generation assets. The individual components of these regulatory assets are being amortized over the respective lives of the underlying generation facilities, consistent with the period over which the related revenues are recognized. (3 ) Includes costs of responding to catastrophic events that have been declared a disaster or state of emergency by competent federal or state authorities. As of December 31, 2021 and 2020, $49 million in COVID-19 related costs was recorded to CEMA regulatory assets. Recovery of CEMA costs is subject to CPUC review and approval. (4) Balance as of December 31, 2021 represents incremental wildfire claims and outside legal expenses related to the 2021 Dixie fire. Balance as of December 31, 2020 is comprised of incremental wildfire liability insurance premium costs for the period July 26, 2017 through December 31, 2019. Recovery of WEMA costs is subject to CPUC review and approval. (5) Includes costs associated with the implementation of regulations and requirements adopted to protect the public from potential fire hazards associated with overhead power line facilities and nearby aerial communication facilities that have not been previously authorized in another proceeding. Recovery of FHPMA costs is subject to CPUC review and approval. (6) Includes costs associated with the 2019 WMP for the period January 1, 2019 through June 4, 2019 and other incremental costs associated with fire risk mitigation. Recovery of FRMMA costs is subject to CPUC review and approval. (7) Includes costs associated with the 2019 WMP for the period June 5, 2019 through December 31, 2019 and the 2020 WMP for the period of January 1, 2020 through December 31, 2020 and the 2021 WMP for the period of January 1, 2021 through December 31, 2021. Recovery of WMPMA costs is subject to CPUC review and approval. (8) Represents cumulative differences between amounts recognized for ratemaking purposes and expense recognized in accordance with GAAP. (9) Represents excess liability insurance premium costs recorded to RTBA and adjustment mechanism for costs determined in other proceedings, as authorized in the 2020 GRC and 2019 GT&S rate cases, respectively. (10) Includes costs associated with certain wildfire mitigation activities for the period January 1, 2020 through December 31, 2021 . Noncurrent balance represents costs above 115% of adopted revenue requirements, which are subject to CPUC review and approval. (11) The GRC memorandum accounts record the difference between the gas and electric revenue requirements in effect on January 1, 2020 and through February 28, 2021 as authorized by the CPUC in December 2020. These amounts will be recovered through rates over 22 months, beginning March 1, 2021. (12) Represents costs from routine vegetation management and EVM activities previously recorded in the FRMMA/WMPMA, and tree mortality and fire risk reduction work previously recorded in CEMA for the period January 1, 2020 through December 31, 2021 . Recovery of VMBA costs above 120% of adopted revenue requirements is subject to CPUC review and approval. (13) On April 16, 2020, the CPUC passed a resolution that established the CPPMA to recover costs associated with customer protections, including higher uncollectible costs related to a moratorium on electric and gas service disconnections for residential and small business customers. The CPPMA applies only to certain residential and small business customers and was approved on July 27, 2020 with an effective date of March 4, 2020. As of December 31, 2021, the Utility had recorded an under-collection of $30 million, representing incremental bad debt expense over what was collected in rates for the period the CPPMA was in effect. The remaining $19 million is associated with program costs and higher accounts receivable financing costs. Recovery of CPPMA costs is subject to CPUC review and approval.
Long-Term Regulatory Liabilities	Long-term regulatory liabilities are comprised of the following: Balance at December 31, (in millions) 2021 2020 Cost of removal obligations (1) $ 7,306 $ 6,905 Recoveries in excess of AROs (2) 388 458 Public purpose programs (3) 946 948 Employee benefit plans (4) 1,229 995 Transmission tower wireless licenses (5) 446 — SFGO sale (6) 343 — Other 1,341 1,118 Total long-term regulatory liabilities $ 11,999 $ 10,424 (1) Represents the cumulative differences between the recorded costs to remove assets and amounts collected in rates for expected costs to remove assets. (2) Represents the cumulative differences between ARO expenses and amounts collected in rates. Decommissioning costs related to the Utility’s nuclear facilities are recovered through rates and are placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on these nuclear decommissioning trust investments. See Note 11 below. (3) Represents amounts received from customers designated for public purpose program costs expected to be incurred beyond the next 12 months, primarily related to energy efficiency programs. (4) Represents cumulative differences between incurred costs and amounts collected in rates for post-retirement medical, post-retirement life and long-term disability plans. (5) Represents the portion of the net proceeds received from the sale of transmission tower wireless licenses that will be returned to customers. Of the $446 million, $311 million and $135 million will be refunded to FERC and CPUC jurisdiction customers, respectively. See Note 3 above. (6) Represents the noncurrent portion of the net gain on the sale of the SFGO, which closed on September 17, 2021, that will be distributed to customers over a five-year period, beginning in 2022.
Current Regulatory Balancing Accounts Receivable	Current regulatory balancing accounts receivable and payable are comprised of the following: Receivable (in millions) 2021 2020 Gas distribution and transmission $ — $ 102 Energy procurement 310 413 Public purpose programs 321 292 Fire hazard prevention memorandum account 50 121 Fire risk mitigation memorandum account 14 33 Wildfire mitigation plan memorandum account 67 161 Wildfire mitigation balancing account 91 27 General rate case memorandum accounts 468 313 Vegetation management balancing account 127 115 Insurance premium costs 605 135 Wildfire expense memorandum account 440 — Residential uncollectibles balancing accounts 127 — Other 379 289 Total regulatory balancing accounts receivable $ 2,999 $ 2,001
Current Regulatory Balancing Accounts Payable	Payable (in millions) 2021 2020 Electric distribution $ 121 $ 55 Electric transmission 24 267 Gas distribution and transmission 83 76 Energy procurement 211 158 Public purpose programs 259 410 Nuclear decommissioning adjustment mechanism 137 — Other 286 279 Total regulatory balancing accounts payable $ 1,121 $ 1,245

DEBT (Tables)

DEBT (Tables)	12 Months Ended
DEBT (Tables)	Dec. 31, 2021
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	The following table summarizes PG&E Corporation’s and the Utility’s outstanding borrowings and availability under their credit facilities at December 31, 2021: (in millions) Termination Maximum Facility Limit Loans Outstanding Letters of Credit Outstanding Facility Utility revolving credit facility June 2026 $ 4,000 (1) $ 1,885 $ 692 $ 1,423 Utility term loan credit facility October 2022 (2) 1,441 (2) 1,441 (2) — — Utility receivables securitization program (3) September 2023 1,000 (4) 974 — — (4) PG&E Corporation revolving credit facility June 2024 500 — — 500 Total credit facilities $ 6,941 $ 4,300 $ 692 $ 1,923 (1) Includes a $1.5 billion letter of credit sublimit. (2 On February 8, 2022, the Utility amended the Utility Term Loan Credit Agreement to, among other things, extend the maturity date of the 18-Month Tranche Loans to January 1, 2023 for those lenders who consented to such extension; the 18-Month Tranche Loans of the non-consenting lenders in an amount equal to $142.5 million were paid in full as of February 8, 2022. (3) On October 5, 2020, the Utility entered into an accounts receivable securitization program (the “Receivables Securitization Program”), providing for the sale of a portion of the Utility's accounts receivable to the SPV, a limited liability company wholly owned by the Utility. On September 15, 2021, the Receivables Securitization Program was amended and extended to September 15, 2023. For more information, see “Variable Interest Entities” in Note 3 above. (4) The amount the Utility may borrow under the Receivables Securitization Program is limited to the lesser of the facility limit and the facility availability. The facility availability may vary based on the amount of accounts receivable that the Utility owns that are eligible for sale to the SPV and the portion of those accounts receivable that are sold to the SPV that are eligible for advances by the lenders under the Receivables Securitization Program. As of December 31, 2021, the Receivables Securitization Program had a maximum borrowing base of $974 million and was fully drawn.
Schedule of Long-term Debt	The following table summarizes PG&E Corporation’s and the Utility’s long-term debt: Balance at (in millions) Contractual Interest Rates December 31, 2021 December 31, 2020 PG&E Corporation Term Loan - Stated Maturity: 2025 variable rate (1) $ 2,709 $ 2,709 Senior Secured Notes due 2028 5.00% 1,000 1,000 Senior Secured Notes due 2030 5.25% 1,000 1,000 Less: current portion, net of debt issuance costs (26) — Unamortized discount, net of premium and debt issuance costs (90) (85) Total PG&E Corporation Long-Term Debt 4,593 4,624 Utility First Mortgage Bonds - Stated Maturity: 2022 variable rate (2) 500 500 2022 1.75% 2,500 2,500 2023 1.37% - 4.25% 3,575 1,175 2024 3.40% - 3.75% 800 800 2025 3.45% - 3.50% 1,475 1,475 2026 2.95% - 3.15% 2,551 2,551 2027 2.10% - 3.30% 2,550 2,550 2028 3.00% - 4.65% 1,975 1,175 2030 4.55% 3,100 3,100 2031 2.50% - 3.25% 3,000 2,000 2040 3.30% - 4.50% 2,951 2,951 2041 4.20% - 4.50% 700 250 2042 3.75% - 4.45% 750 750 2043 4.60% 375 375 2044 4.75% 675 675 2045 4.30% 600 600 2046 4.00% - 4.25% 1,050 1,050 2047 3.95% 850 850 2050 3.50% - 4.95% 5,025 5,025 Less: current portion, net of debt issuance costs (2,996) — Unamortized discount, net of premium and debt issuance costs (190) (182) Total Utility First Mortgage Bonds 31,816 30,170 Recovery Bonds 1.46% - 2.82% 860 — Less: current portion (18) — Credit Facilities Receivables securitization program - Stated Maturity: 2023 variable rate (3) 974 1,000 18-month Term Loan - Stated Maturity: 2022 variable rate (4) 1,441 1,500 Less: current portion (1,441) — Unamortized discount, net of premium and debt issuance costs — (6) Total Utility Long-Term Debt 33,632 32,664 Total PG&E Corporation Consolidated Long-Term Debt $ 38,225 $ 37,288 (1) At December 31, 2021 and 2020, the contractual LIBOR-based interest rate on the term loan was 3.50% and 5.50%, respectively. (2) At December 31, 2021 and 2020, the contractual LIBOR-based interest rate on $500 million of the first mortgage bonds was 1.69% and 1.70%, respectively. (3) At December 31, 2021 and 2020, the contractual LIBOR-based interest rate on the receivables securitization program was 1.30% and 1.57%, respectively. (4) At December 31, 2021 and 2020, the contractual LIBOR-based interest rate on the term loan was 2.38% and 2.44%, respectively.
Schedule of Contractual Repayment Schedule	PG&E Corporation’s and the Utility’s combined stated long-term debt principal repayment amounts at December 31, 2021 are reflected in the table below: (in millions, except interest rates) 2022 2023 2024 2025 2026 Thereafter Total PG&E Corporation Average fixed interest rate — % — % — % — % — % 5.13 % 5.13 % Fixed rate obligations $ — $ — $ — $ — $ — $ 2,000 $ 2,000 Variable interest rate as of December 31, 2021 3.50 % 3.50 % 3.50 % 3.50 % — % — % 3.50 % Variable rate obligations $ 28 $ 28 $ 28 $ 2,625 $ — $ — $ 2,709 Utility Average fixed interest rate 1.75 % 2.26 % 3.60 % 3.47 % 3.10 % 3.90 % 3.49 % Fixed rate obligations $ 2,500 $ 3,575 $ 800 $ 1,475 $ 2,551 $ 23,601 $ 34,502 Variable interest rate as of December 31, 2021 2.20 % various (1) — % — % — % — % various (1) Variable rate obligations $ 1,941 $ 974 $ — $ — $ — $ — $ 2,915 Total consolidated debt $ 4,469 $ 4,577 $ 828 $ 4,100 $ 2,551 $ 25,601 $ 42,126 (1) At December 31, 2021, the average interest rates for the Receivables Securitization Program, the first mortgage bonds due 2022 and the 18-month term loan were 1.30%, 1.69% and 2.38% respectively.

COMMON STOCK AND SHARE-BASED _2

COMMON STOCK AND SHARE-BASED COMPENSATION (Tables)	12 Months Ended
COMMON STOCK AND SHARE-BASED COMPENSATION (Tables)	Dec. 31, 2021
Common Stock And Share-Based Compensation [Abstract]
Schedule of Compensation Expense for Share-based Incentive Awards	The following table provides a summary of total share-based compensation expense recognized by PG&E Corporation for share-based incentive awards for 2021: (in millions) 2021 2020 2019 Stock Options $ — $ 3 $ 7 Restricted stock units 35 15 21 Performance shares 21 17 22 Total compensation expense (pre-tax) $ 56 $ 35 $ 50 Total compensation expense (after-tax) $ 40 $ 25 $ 35
Summary of Stock Option Activity	The following table summarizes stock option activity for PG&E Corporation and the Utility for 2021: Number of Weighted Average Grant- Weighted Average Remaining Contractual Term Aggregate Intrinsic Value Outstanding at January 1 2,221,247 $ 7.45 $ — Granted (1) — — — Exercised — — — Forfeited or expired (25,413) 10.23 — Outstanding at December 31 2,195,834 7.42 4.33 — Vested or expected to vest at December 31 2,195,834 7.42 4.33 — Exercisable at December 31 2,195,834 $ 7.42 4.33 $ — (1) Represents additional payout of existing stock option grants.
Schedule of Restricted Stock Units	The following table summarizes restricted stock unit activity for 2021: Number of Weighted Average Grant- Nonvested at January 1 890,353 $ 23.05 Granted 10,352,117 11.01 Vested (743,672) 25.20 Forfeited (408,423) 11.67 Nonvested at December 31 10,090,375 $ 11.00
Schedule of Performance Shares	The following table summarizes activity for performance shares in 2021: Number of Weighted Average Grant- Nonvested at January 1 7,288,782 $ 9.16 Granted 2,714,645 11.83 Vested — — Forfeited (1) (1,436,418) 11.35 Nonvested at December 31 8,567,009 $ 9.64 (1) Includes performance shares that expired with zero value as performance targets were not met.

EARNINGS PER SHARE (Tables)

EARNINGS PER SHARE (Tables)	12 Months Ended
EARNINGS PER SHARE (Tables)	Dec. 31, 2021
Earnings Per Share [Abstract]
Earnings Per Share	The following is a reconciliation of PG&E Corporation’s income (loss) available for common shareholders and weighted average common shares outstanding for calculating diluted EPS for 2021, 2020, and 2019. Year Ended December 31, (in millions, except per share amounts) 2021 2020 2019 Loss attributable to common shareholders $ (102) $ (1,318) $ (7,656) Weighted average common shares outstanding, basic 1,985 1,257 528 Add incremental shares from assumed conversions: Employee share-based compensation — — — Equity Units — — — Weighted average common share outstanding, diluted 1,985 1,257 528 Total Loss per common share, diluted $ (0.05) $ (1.05) $ (14.50)

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
INCOME TAXES (Tables)	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	The significant components of income tax provision (benefit) by taxing jurisdiction were as follows: PG&E Corporation Utility Year Ended December 31, (in millions) 2021 2020 2019 2021 2020 2019 Current: Federal $ — $ (26) $ 1 $ — $ (26) $ 4 State 1 (34) 101 — (34) 94 Deferred: Federal 543 258 (2,361) 588 290 (2,363) State 296 171 (1,136) 316 185 (1,137) Tax credits (4) (7) (5) (4) (7) (5) Income tax provision (benefit) $ 836 $ 362 $ (3,400) $ 900 $ 408 $ (3,407)
Schedule of Deferred Tax Assets and Liabilities	The following tables describe net deferred income tax assets and liabilities: PG&E Corporation Utility Year Ended December 31, (in millions) 2021 2020 2021 2020 Deferred income tax assets: Tax carryforwards $ 5,628 $ 7,641 $ 5,425 $ 7,529 Compensation 185 187 108 109 Wildfire-related claims (1) 1,723 544 1,723 544 Operating lease liability 346 489 346 488 Transmission tower wireless licenses 266 — 266 — Other (2) 278 212 293 219 Total deferred income tax assets $ 8,426 $ 9,073 $ 8,161 $ 8,889 Deferred income tax liabilities: Property related basis differences 8,847 8,311 8,835 8,300 Regulatory balancing accounts 1,193 763 1,193 763 Debt financing costs 501 526 501 526 Operating lease right of use asset 346 489 346 488 Income tax regulatory asset (3) 517 254 517 254 Other (4) 199 128 178 128 Total deferred income tax liabilities $ 11,603 $ 10,471 $ 11,570 $ 10,459 Total net deferred income tax liabilities $ 3,177 $ 1,398 $ 3,409 $ 1,570 (1) Amounts primarily relate to wildfire-related claims, net of estimated insurance recoveries, and legal and other costs related to various wildfires that have occurred in PG&E Corporation’s and the Utility’s service territory over the past several years. (2) Amounts include benefits, environmental reserve, and customer advances for construction. (3) Represents the tax gross up portion of the deferred income tax for the cumulative differences between amounts recognized for ratemaking purposes and amounts recognized for tax, including the impact of changes in net deferred taxes associated with a lower federal income tax rate as a result of the Tax Act.
Schedule of Effective Income Tax Rate Reconciliation	The following table reconciles income tax expense at the federal statutory rate to the income tax provision: PG&E Corporation Utility Year Ended December 31, 2021 2020 2019 2021 2020 2019 Federal statutory income tax rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) in income tax rate resulting from: State income tax (net of federal benefit) (1) 31.3 (15.3) 7.5 24.1 19.1 7.5 Effect of regulatory treatment of fixed asset differences (2) (71.5) 39.0 2.8 (51.6) (44.9) 2.8 Tax credits (1.7) 1.5 0.1 (1.2) (1.7) 0.1 Fire Victim Trust (3) 127.3 (44.9) — 91.9 51.7 — Bankruptcy and emergence — (37.6) — — 2.4 — Other, net (4) 5.3 (2.1) (0.6) 2.6 2.2 (0.5) Effective tax rate 111.7 % (38.4) % 30.8 % 86.8 % 49.8 % 30.9 % (1) Includes the effect of state flow-through ratemaking treatment. (2) Includes the effect of federal flow-through ratemaking treatment for certain property-related costs. For these temporary tax differences, PG&E Corporation and the Utility recognize the deferred tax impact in the current period and record offsetting regulatory assets and liabilities. Therefore, PG&E Corporation’s and the Utility’s effective tax rates are impacted as these differences arise and reverse. PG&E Corporation and the Utility recognize such differences as regulatory assets or liabilities as it is probable that these amounts will be recovered from or returned to customers in future rates. In 2021, 2020, and 2019, the amounts also reflect the impact of the amortization of excess deferred tax benefits to be refunded to customers as a result of the Tax Act passed in December 2017. (3) The Utility includes an adjustment for a DTA write-off associated with the grantor trust election for the Fire Victim Trust in 2021 and an adjustment for the DTA write-off for difference between the liability recorded related to the TCC RSA and the ultimate value of PG&E Corporation stock contributed to the Fire Victim Trust in 2020. PG&E Corporation includes the same adjustment as the Utility in 2021 and 2020 as well as a permanent non-deductible equity backstop premium expense in 2020. This combined with a pre-tax loss and a pre-tax income for PG&E Corporation and the Utility, respectively in 2020, accounts for the remaining difference. (4) These amounts primarily represent the impact of tax audit settlements and non-tax deductible penalty costs in 2021 and 2020.
Schedule of Change in Unrecognized Tax Benefits	The following table reconciles the changes in unrecognized tax benefits: PG&E Corporation Utility (in millions) 2021 2020 2019 2021 2020 2019 Balance at beginning of year $ 437 $ 420 $ 377 $ 437 $ 420 $ 377 Reductions for tax position taken during a prior year (23) (43) (1) (23) (43) (1) Additions for tax position taken during the current year 85 60 44 85 60 44 Settlements (1) — — (1) — — Balance at end of year $ 498 $ 437 $ 420 $ 498 $ 437 $ 420
Schedule of Operating Loss and Tax Credit Carryforward Balances	The following table describes PG&E Corporation’s operating loss and tax credit carryforward balances: (in millions) December 31, 2021 Expiration Federal: Net operating loss carryforward - Pre-2018 $ 3,600 2031 - 2036 Net operating loss carryforward - Post-2017 17,467 N/A Tax credit carryforward 144 2029 - 2041 State: Net operating loss carryforward $ 18,853 2039 - 2041 Tax credit carryforward 122 Various

DERIVATIVES (Tables)

DERIVATIVES (Tables)	12 Months Ended
DERIVATIVES (Tables)	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Volumes of Outstanding Derivative Contracts	The volumes of the Utility’s outstanding derivatives were as follows: Contract Volume At December 31, Underlying Product Instruments 2021 2020 Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 173,361,635 146,642,863 Options 14,420,000 14,140,000 Electricity (Megawatt-hours) Forwards, Futures and Swaps 10,283,639 9,435,830 Options 288,000 — Congestion Revenue Rights (3) 239,857,610 266,091,470 (1) Amounts shown are for the combined positions of the electric fuels and core gas supply portfolios. (2) Million British Thermal Units. (3) CRRs are financial instruments that enable the holders to manage variability in electric energy congestion charges due to transmission grid limitations.
Outstanding Derivative Balances	At December 31, 2021, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 58 $ (9) $ 152 $ 201 Other noncurrent assets – other 169 — — 169 Current liabilities – other (53) 9 18 (26) Noncurrent liabilities – other (216) — — (216) Total commodity risk $ (42) $ — $ 170 $ 128 At December 31, 2020, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 33 $ — $ 115 $ 148 Other noncurrent assets – other 136 — — 136 Current liabilities – other (38) — 15 (23) Noncurrent liabilities – other (204) — 10 (194) Total commodity risk $ (73) $ — $ 140 $ 67

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
FAIR VALUE MEASUREMENTS (Tables)	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Assets and Liabilities Measured at Fair Value on a Recurring Basis	Assets and liabilities measured at fair value on a recurring basis for PG&E Corporation and the Utility are summarized below. Assets held in rabbi trusts are held by PG&E Corporation and not the Utility. Fair Value Measurements At December 31, 2021 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 289 $ — $ — $ — $ 289 Nuclear decommissioning trusts Short-term investments 22 — — — 22 Global equity securities 2,504 — — — 2,504 Fixed-income securities 1,158 866 — — 2,024 Assets measured at NAV — — — — 31 Total nuclear decommissioning trusts (2) 3,684 866 — — 4,581 Price risk management instruments (Note 10) Electricity — 9 214 6 229 Gas — 4 — 137 141 Total price risk management instruments — 13 214 143 370 Rabbi trusts Fixed-income securities — 104 — — 104 Life insurance contracts — 76 — — 76 Total rabbi trusts — 180 — — 180 Long-term disability trust Short-term investments 6 — — — 6 Assets measured at NAV — — — — 132 Total long-term disability trust 6 — — — 138 TOTAL ASSETS $ 3,979 $ 1,059 $ 214 $ 143 $ 5,558 Liabilities: Price risk management instruments (Note 10) Electricity $ — $ 11 $ 248 $ (24) $ 235 Gas — 10 — (3) 7 TOTAL LIABILITIES $ — $ 21 $ 248 $ (27) $ 242 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. (2) Represents amount before deducting $783 million, primarily related to deferred taxes on appreciation of investment value. Fair Value Measurements At December 31, 2020 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 470 $ — $ — $ — $ 470 Nuclear decommissioning trusts Short-term investments 27 — — — 27 Global equity securities 2,398 — — — 2,398 Fixed-income securities 924 835 — — 1,759 Assets measured at NAV — — — — 25 Total nuclear decommissioning trusts (2) 3,349 835 — — 4,209 Price risk management instruments (Note 10) Electricity — 2 166 2 170 Gas — 1 — 113 114 Total price risk management instruments — 3 166 115 284 Rabbi trusts Fixed-income securities — 106 — — 106 Life insurance contracts — 79 — — 79 Total rabbi trusts — 185 — — 185 Long-term disability trust Short-term investments 9 — — — 9 Assets measured at NAV — — — — 158 Total long-term disability trust 9 — — — 167 TOTAL ASSETS $ 3,828 $ 1,023 $ 166 $ 115 $ 5,315 Liabilities: Price risk management instruments (Note 10) Electricity — 1 238 (25) 214 Gas — 3 — — 3 TOTAL LIABILITIES $ — $ 4 $ 238 $ (25) $ 217 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. (2) Represents amount before deducting $671 million, primarily related to deferred taxes on appreciation of investment value.
Uncertainty Analysis	Fair Value at (in millions) At December 31, 2021 Valuation Unobservable Fair Value Measurement Assets Liabilities Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 188 $ 93 Market approach CRR auction prices $ (40.77) - 2,265.94 / 0.40 Power purchase agreements $ 26 $ 155 Discounted cash flow Forward prices $ (7.97) - 256.20 / 47.17 (1) Represents price per megawatt-hour. (2) Unobservable inputs were weighted by the relative fair value of the instruments. Fair Value at (in millions) At December 31, 2020 Valuation Unobservable Fair Value Measurement Assets Liabilities Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 153 $ 74 Market approach CRR auction prices $ (320.25) - 320.25 / 0.30 Power purchase agreements $ 13 $ 164 Discounted cash flow Forward prices $ 12.56 - 148.30 / 35.52 (1) Represents price per megawatt-hour.
Level 3 Reconciliation	The following table presents the reconciliation for Level 3 price risk management instruments for the years ended December 31, 2021 and 2020, respectively: Price Risk Management Instruments (in millions) 2021 2020 Asset (liability) balance as of January 1 $ (72) $ 5 Net realized and unrealized gains: Included in regulatory assets and liabilities or balancing accounts (1) 38 (77) Asset (liability) balance as of December 31 $ (34) $ (72) (1) The costs related to price risk management activities are fully passed through to customers in rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted.
Carrying Amount and Fair Value of Financial Instruments	The carrying amount and fair value of PG&E Corporation’s and the Utility’s long-term debt instruments were as follows (the table below excludes financial instruments with carrying values that approximate their fair values): At December 31, 2021 2020 (in millions) Carrying Amount Level 2 Fair Value Carrying Amount Level 2 Fair Value Debt (Note 5) PG&E Corporation $ 4,619 $ 4,796 $ 1,901 $ 2,175 Utility 31,816 35,803 29,664 32,632
Schedule of Unrealized Gains (Losses) Related to Available-for-sale Investments	The following table provides a summary of equity securities and available-for-sale debt securities: (in millions) Amortized Total Total Total Fair As of December 31, 2021 Nuclear decommissioning trusts Short-term investments $ 22 $ — $ — $ 22 Global equity securities 479 2,066 (10) 2,535 Fixed-income securities 1,938 98 (12) 2,024 Total (1) $ 2,439 $ 2,164 $ (22) $ 4,581 As of December 31, 2020 Nuclear decommissioning trusts Short-term investments $ 27 $ — $ — $ 27 Global equity securities 543 1,881 (1) 2,423 Fixed-income securities 1,610 152 (3) 1,759 Total (1) $ 2,180 $ 2,033 $ (4) $ 4,209 (1) Represents amounts before deducting $783 million and $671 million at December 31, 2021 and 2020, respectively, primarily related to deferred taxes on appreciation of investment value.
Schedule of Long Term Debt Repayments	The fair value of fixed-income securities by contractual maturity is as follows: As of (in millions) December 31, 2021 Less than 1 year $ 97 1–5 years 495 5–10 years 480 More than 10 years 952 Total maturities of fixed-income securities $ 2,024
Schedule of Activity for Debt and Equity Securities	The following table provides a summary of activity for the fixed-income and equity securities: (in millions) 2021 2020 2019 Proceeds from sales and maturities of nuclear decommissioning investments $ 1,678 $ 1,518 $ 956 Gross realized gains on securities 286 159 69 Gross realized losses on securities (19) (41) (14)

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	12 Months Ended
EMPLOYEE BENEFIT PLANS (Tables)	Dec. 31, 2021
Employee Benefit and Share-based Payment Arrangement, Noncash Expense [Abstract]
Reconciliation of Changes in Plan Assets Benefit Obligations and Funded Status	The following tables show the reconciliation of changes in plan assets, benefit obligations, and the plans’ aggregate funded status for pension benefits and other benefits for PG&E Corporation during 2021 and 2020: Pension Plan (in millions) 2021 2020 Change in plan assets: Fair value of plan assets at beginning of year $ 20,759 $ 18,547 Actual return on plan assets 1,693 2,736 Company contributions 335 343 Benefits and expenses paid (892) (867) Fair value of plan assets at end of year $ 21,895 $ 20,759 Change in benefit obligation: Benefit obligation at beginning of year $ 23,172 $ 20,525 Service cost for benefits earned 587 530 Interest cost 645 713 Actuarial (gain) loss (1) (752) 2,271 Plan amendments — — Benefits and expenses paid (893) (867) Benefit obligation at end of year (2) $ 22,759 $ 23,172 Funded Status: Current liability $ (9) $ (3) Noncurrent liability (856) (2,410) Net liability at end of year $ (865) $ (2,413) (1) The actuarial gain for the year ended December 31, 2021 was due to an increase in the discount rate used to measure the projected benefit obligation, offset by unfavorable changes in the demographic assumptions. The actuarial loss for the year ended December 31, 2020 was due to a decrease in the discount rate used to measure the projected benefit obligation. (2) PG&E Corporation’s accumulated benefit obligation was $20.4 billion and $20.7 billion at December 31, 2021 and 2020, respectively. Postretirement Benefits Other than Pensions (in millions) 2021 2020 Change in plan assets: Fair value of plan assets at beginning of year $ 2,995 $ 2,678 Actual return on plan assets 193 379 Company contributions 10 26 Plan participant contribution 80 81 Benefits and expenses paid (176) (169) Fair value of plan assets at end of year $ 3,102 $ 2,995 Change in benefit obligation: Benefit obligation at beginning of year $ 1,876 $ 1,832 Service cost for benefits earned 63 61 Interest cost 51 63 Actuarial gain (1) (152) (14) Benefits and expenses paid (156) (149) Federal subsidy on benefits paid 4 3 Plan participant contributions 80 80 Benefit obligation at end of year $ 1,766 $ 1,876 Funded Status: (2) Noncurrent asset $ 1,340 $ 1,153 Noncurrent liability (4) (34) Net asset at end of year $ 1,336 $ 1,119 (1) The actuarial gain for the year ended December 31, 2021 was primarily due to an increase in the discount rate used to measure the accumulated benefit obligations and favorable claims cost changes. The actuarial gain for the year ended December 31, 2020 was primarily due to favorable changes in the demographic and medical cost assumptions, offset by a decrease in the discount rate used to measure the projected benefit obligation. (2) At December 31, 2021 and 2020, the postretirement medical plan was in an overfunded position and the postretirement life insurance plan was in an underfunded position. The projected benefit obligation and the fair value of plan assets for the postretirement life insurance plan were $363 million and $359 million as of December 31, 2021, and $377 million and $343 million as of December 31, 2020, respectively.
Components of Net Periodic Benefit Cost	Net periodic benefit cost as reflected in PG&E Corporation’s Consolidated Statements of Income was as follows: Pension Plan (in millions) 2021 2020 2019 Service cost for benefits earned (1) $ 587 $ 530 $ 443 Interest cost 645 713 758 Expected return on plan assets (1,046) (1,044) (906) Amortization of prior service cost (6) (6) (6) Amortization of net actuarial loss 6 3 3 Net periodic benefit cost 186 196 292 Less: transfer to regulatory account (2) 147 136 42 Total expense recognized $ 333 $ 332 $ 334 (1) A portion of service costs are capitalized pursuant to ASU 2017-07. (2) The Utility recorded these amounts to a regulatory account as they are probable of recovery through future rates. Postretirement Benefits Other than Pensions (in millions) 2021 2020 2019 Service cost for benefits earned (1) $ 63 $ 61 $ 56 Interest cost 51 63 76 Expected return on plan assets (137) (138) (123) Amortization of prior service cost 14 14 14 Amortization of net actuarial loss (33) (21) (3) Net periodic benefit cost $ (42) $ (21) $ 20 (1) A portion of service costs are capitalized pursuant to ASU 2017-07.
Schedule of Assumptions Used in Calculating Projected Benefit Cost and Net Periodic Benefit Cost	The following weighted average year-end actuarial assumptions were used in determining the plans’ projected benefit obligations and net benefit costs. Pension Plan PBOP Plans December 31, December 31, 2021 2020 2019 2021 2020 2019 Discount rate 3.03 % 2.77 % 3.46 % 2.97 - 3.04% 2.67 - 2.80 % 3.37 - 3.47% Rate of future compensation increases 3.80 % 3.80 % 3.90 % N/A N/A N/A Expected return on plan assets 5.50 % 5.10 % 5.70 % 3.30 - 6.40% 3.10 - 6.10 % 3.50 - 6.60% Interest crediting rate for cash balance plan 1.95 % 1.95 % 2.11 % N/A N/A N/A
Target Asset Allocation Percentages	The target asset allocation percentages for major categories of trust assets for pension and other benefit plans are as follows: Pension Plan PBOP Plans 2022 2021 2020 2022 2021 2020 Global equity securities 30 % 30 % 30 % 26 % 36 % 28 % Absolute return 2 % 2 % 2 % 1 % 1 % 2 % Real assets 8 % 8 % 8 % 3 % 5 % 8 % Fixed-income securities 60 % 60 % 60 % 70 % 58 % 62 % Total 100 % 100 % 100 % 100 % 100 % 100 %
Schedule of Changes in Fair Value of Plan Assets	The following tables present the fair value of plan assets for pension and other benefits plans by major asset category at December 31, 2021 and 2020. Fair Value Measurements At December 31, 2021 2020 (in millions) Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Pension Plan: Short-term investments $ 552 $ 255 $ — $ 807 $ 334 $ 408 $ — $ 742 Global equity securities 2,074 424 — 2,498 1,875 — — 1,875 Absolute Return — 1 — 1 1 1 — 2 Real assets 632 — — 632 517 — — 517 Fixed-income securities 2,729 7,388 27 10,144 2,467 7,154 12 9,633 Assets measured at NAV — — — 7,972 — — — 8,224 Total $ 5,987 $ 8,068 $ 27 $ 22,054 $ 5,194 $ 7,563 $ 12 $ 20,993 PBOP Plans: Short-term investments $ 31 $ — $ — $ 31 $ 37 $ — $ — $ 37 Global equity securities 105 — — 105 173 — — 173 Real assets 34 — — 34 54 — — 54 Fixed-income securities 776 875 1 1,652 481 715 1 1,197 Assets measured at NAV — — — 1,296 — — — 1,549 Total $ 946 $ 875 $ 1 $ 3,118 $ 745 $ 715 $ 1 $ 3,010 Total plan assets at fair value $ 25,172 $ 24,003
Schedule of Level 3 Reconciliation	The following table is a reconciliation of changes in the fair value of instruments for the pension plan that have been classified as Level 3 for the years ended December 31, 2021 and 2020: (in millions) For the year ended December 31, 2021 Fixed-Income Balance at beginning of year $ 12 Actual return on plan assets: Relating to assets still held at the reporting date 6 Relating to assets sold during the period (7) Purchases, issuances, sales, and settlements: Purchases 22 Settlements (6) Balance at end of year $ 27 (in millions) For the year ended December 31, 2020 Fixed-Income Balance at beginning of year $ 15 Actual return on plan assets: Relating to assets still held at the reporting date 2 Relating to assets sold during the period (3) Purchases, issuances, sales, and settlements: Purchases 11 Settlements (13) Balance at end of year $ 12
Schedule of Estimated Benefits Expected to be Paid	As of December 31, 2021, the estimated benefits expected to be paid and the estimated federal subsidies expected to be received in each of the next five fiscal years, and in aggregate for the five fiscal years thereafter, are as follows: (in millions) Pension PBOP Federal 2022 869 81 (3) 2023 954 85 (3) 2024 988 89 (3) 2025 1018 88 (3) 2026 1,046 91 (3) Thereafter in the succeeding five years 5,533 466 (3)

RELATED PARTY AGREEMENTS AND _2

RELATED PARTY AGREEMENTS AND TRANSACTIONS (Tables)	12 Months Ended
RELATED PARTY AGREEMENTS AND TRANSACTIONS (Tables)	Dec. 31, 2021
Related Party Transactions [Abstract]
Schedule of Significant Related Party Transactions	The Utility’s significant related party transactions were: Year Ended December 31, (in millions) 2021 2020 2019 Utility revenues from: Administrative services provided to PG&E Corporation $ 3 $ 3 $ 4 Utility expenses from: Administrative services received from PG&E Corporation $ 82 $ 108 $ 107 Utility employee benefit due to PG&E Corporation 39 34 42

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES (Tables)	12 Months Ended
WILDFIRE-RELATED CONTINGENCIES (Tables)	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Summary of Wildfire-Related Claims	The following table presents changes in the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimable range of losses for claims arising from the 2019 Kincade fire since December 31, 2019. Loss Accrual (in millions) Balance at December 31, 2019 $ — Accrued Losses 625 Payments — Balance at December 31, 2020 625 Accrued Losses 175 Payments (31) Balance at December 31, 2021 $ 769 The following table presents changes in the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimable range of losses for claims arising from the 2020 Zogg fire since December 31, 2019. Loss Accrual (in millions) Balance at December 31, 2019 $ — Accrued Losses 275 Payments — Balance at December 31, 2020 275 Accrued Losses 100 Payments (164) Balance at December 31, 2021 $ 211 Total probable recoveries for the 2021 Dixie fire as of December 31, 2021 are: Potential Recovery Source (in millions) 2021 Dixie fire Insurance $ 563 FERC TO rates 101 WEMA 347 Wildfire Fund 150 Probable recoveries at December 31, 2021 $ 1,161 The balances for insurance receivables with respect to wildfires are included in Other accounts receivable in PG&E Corporation’s and the Utility’s Consolidated Balance Sheets: Insurance Receivable (in millions) 2021 Dixie fire 2020 Zogg fire 2019 Kincade fire 2018 Camp fire 2017 Northern California wildfires 2015 Butte fire Total Balance at December 31, 2019 $ — $ — $ — $ 1,380 $ 808 $ 50 $ 2,238 Accrued insurance recoveries — 219 430 — — — 649 Reimbursements — — — (1,380) (783) (50) (2,213) Balance at December 31, 2020 — 219 430 — 25 — 674 Accrued insurance recoveries (1) 563 118 — — — — 681 Reimbursements (2) — (67) (16) — (25) — (108) Balance at December 31, 2021 $ 563 $ 270 $ 414 $ — $ — $ — $ 1,247 (1) During the fourth quarter of 2021, the accrued insurance recoveries decreased for the 2021 Dixie fire with a corresponding increase for the 2020 Zogg fire for $6.5 million.

OTHER CONTINGENCIES AND COMMI_2

OTHER CONTINGENCIES AND COMMITMENTS (Tables)	12 Months Ended
OTHER CONTINGENCIES AND COMMITMENTS (Tables)	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Schedule of Expense and Capital Expenditures	The amounts set forth in the table below include actual recorded costs and forecasted cost estimates as of the date of the settlement agreement for expenses and capital expenditures which the Utility has incurred or planned to incur to comply with its legal obligations to provide safe and reliable service. While actual costs incurred for certain cost categories are different than what was assumed in the settlement agreement, the Utility recorded $1.625 billion of the disallowed costs for the year ended December 31, 2020. (in millions) Description (1) Expense Capital Total Distribution Safety Inspections and Repairs Expense (FRMMA/WMPMA) $ 236 $ — $ 236 Transmission Safety Inspections and Repairs Expense (TO) (2) 433 — 433 Vegetation Management Support Costs (FHPMA) 36 — 36 2017 Northern California Wildfires CEMA Expense and Capital (CEMA) 82 66 148 2018 Camp Fire CEMA Expense (CEMA) 435 — 435 2018 Camp Fire CEMA Capital for Restoration (CEMA) — 253 253 2018 Camp Fire CEMA Capital for Temporary Facilities (CEMA) — 84 84 Total $ 1,222 $ 403 $ 1,625 (1) All amounts included in the table reflect actual recorded costs for 2019 and 2020.
Schedule of Environmental Remediation Liability	The Utility’s environmental remediation liability is primarily included in non-current liabilities on the Consolidated Balance Sheets and is comprised of the following: Balance at (in millions) December 31, 2021 December 31, 2020 Topock natural gas compressor station $ 299 $ 303 Hinkley natural gas compressor station 123 132 Former MGP sites owned by the Utility or third parties (1) 667 659 Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites (2) 104 111 Fossil fuel-fired generation facilities and sites (3) 70 96 Total environmental remediation liability $ 1,263 $ 1,301 (1) Primarily driven by the following sites: San Francisco Beach Street, Vallejo, Napa, and San Francisco East Harbor. (2) Primarily driven by Geothermal landfill and Shell Pond site.
Schedule of Undiscounted Future Expected Power Purchase Agreement Payments	The following table shows the undiscounted future expected obligations under power purchase agreements that have been approved by the CPUC and have met specified construction milestones as well as undiscounted future expected payment obligations for natural gas supplies, natural gas transportation, natural gas storage, and nuclear fuel as of December 31, 2021: Power Purchase Agreements (in millions) Renewable Conventional Other Natural Nuclear Total 2022 $ 2,062 $ 530 $ 61 $ 823 $ 42 $ 3,518 2023 2,043 425 61 191 41 2,761 2024 2,020 282 61 157 27 2,547 2025 2,009 216 61 157 — 2,443 2026 1,948 204 21 140 — 2,313 Thereafter 19,310 539 19 52 — 19,920 Total purchase commitments $ 29,392 $ 2,196 $ 284 $ 1,520 $ 110 $ 33,502
Schedule of Other Commitments	At December 31, 2021, the future minimum payments related to these commitments were as follows: (in millions) Other Commitments 2022 $ 43 2023 65 2024 81 2025 77 2026 74 Thereafter 2,938 Total minimum lease payments $ 3,278

ORGANIZATION AND BASIS OF PRE_2

ORGANIZATION AND BASIS OF PRESENTATION (Details)	12 Months Ended
ORGANIZATION AND BASIS OF PRESENTATION (Details)	Dec. 31, 2021numberOfSegment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of operating segments (segment)	1

BANKRUPTCY FILING (Chapter 11 C

BANKRUPTCY FILING (Chapter 11 Claims Process) (Details) notice in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)notice
Debt Instrument [Line Items]
Proofs of claims \| notice		100
Claims expected to be received	$ 145
Disputed claims and customer refunds	0	$ 242
Current regulatory liabilities expected to be refunded	422
Pacific Gas & Electric Co (Utility)
Debt Instrument [Line Items]
Disputed claims and customer refunds	0	242
Payments for reorganization items	53	400
PG&E Corporation
Debt Instrument [Line Items]
Payments for reorganization items	$ 31	$ 102
Subrogation Wildfire Trust and Fire Victim Trust
Debt Instrument [Line Items]
Proofs of claims \| notice		80

BANKRUPTCY FILING (Schedule of

BANKRUPTCY FILING (Schedule of Debtor Reorganization Items) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reorganizations [Line Items]
Debtor-in-possession financing costs	$ 0	$ 6	$ 114
Legal and other	20	1,969	292
Interest and other	(9)	(16)	(60)
Total reorganization items, net	11	1,959	346
Equity backstop premium expense and bridge loan facility fees
Reorganizations [Line Items]
Legal and other		1,500
PG&E Corporation
Reorganizations [Line Items]
Payments for reorganization items	31	102
Debtor-in-possession financing costs	0	0	17
Legal and other	(1)	1,651	19
Interest and other	0	(2)	(10)
Total reorganization items, net	(1)	1,649	26
Pacific Gas & Electric Co (Utility)
Reorganizations [Line Items]
Payments for reorganization items	53	400
Debtor-in-possession financing costs	0	6	97
Legal and other	21	318	273
Interest and other	(9)	(14)	(50)
Total reorganization items, net	$ 12	$ 310	$ 320

SUMMARY OF SIGNIFICANT ACCOUN_4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Narrative) (Details)	Aug. 15, 2021USD ($)	Feb. 16, 2021USD ($)transmissionTower	Dec. 31, 2021USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2021USD ($)facilitynumberOfFatality	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Nov. 12, 2021USD ($)	Dec. 30, 2020USD ($)	Jul. 12, 2019USD ($)
Public Utility, Property, Plant and Equipment [Line Items]
Period for probable revenue recovery					24 months
Expected credit losses			$ 154,000,000	$ 154,000,000	$ 154,000,000
Allowance for credit loss decrease				207,000,000
Regulatory balancing accounts			2,999,000,000	2,999,000,000	2,999,000,000	$ 2,001,000,000
Decrease in nuclear decommissioning obligation			1,400,000,000
Expected capitalization, proceeds of bond			10,500,000,000	10,500,000,000	10,500,000,000
Expected capitalization, initial contribution			7,500,000,000	7,500,000,000	7,500,000,000
Expected capitalization, annual contribution			300,000,000	300,000,000	300,000,000
Expected wildfire fund allocation metric, percentage										64.20%
Expected wildfire fund allocation metric, initial contribution										$ 4,800,000,000
Expected wildfire fund allocation metric, annual contributions										$ 193,000,000
Expected wildfire fund allocation metric, annual contributions, second									$ 193,000,000
Litigation liability, current			193,000,000	193,000,000	193,000,000
Wildfire fund asset			461,000,000	461,000,000	461,000,000	464,000,000
Litigation contribution, net			$ 5,300,000,000	$ 5,300,000,000	5,300,000,000
Amortization and accretion					$ 517,000,000	413,000,000	$ 0
Monte carlo simulation, historical data, period					12 years
Amortization period					6 years
Percentage assumption change			10.00%	10.00%	10.00%
Insurance receivable			$ 1,247,000,000	$ 1,247,000,000	$ 1,247,000,000	674,000,000	2,238,000,000
Operating lease, payments					$ 2,400,000,000	$ 2,500,000,000
Weighted average remaining lease term			6 years 14 days	6 years 14 days	6 years 14 days	5 years 8 months 12 days
Weighted average discount rate			6.10%	6.10%	6.10%	6.20%
Proceeds from contract liability	$ 106,000,000
Litigation Settlement, Expense
Public Utility, Property, Plant and Equipment [Line Items]
Accelerated amortization					$ 43,000,000
2021 Dixie fire
Public Utility, Property, Plant and Equipment [Line Items]
Insurance receivable			$ 563,000,000	$ 563,000,000	563,000,000	$ 0	$ 0
CPUC
Public Utility, Property, Plant and Equipment [Line Items]
Regulatory balancing accounts			209,000,000	209,000,000	209,000,000
COVID-19 Pandemic protection memorandum account
Public Utility, Property, Plant and Equipment [Line Items]
Regulatory assets			30,000,000	30,000,000	30,000,000
Federal Energy Regulatory Commission
Public Utility, Property, Plant and Equipment [Line Items]
Regulatory assets			12,000,000	12,000,000	12,000,000
Regulatory Balancing Accounts Receivable
Public Utility, Property, Plant and Equipment [Line Items]
Total regulatory balancing accounts			2,999,000,000	2,999,000,000	2,999,000,000	2,001,000,000
Residential uncollectibles balancing accounts \| Regulatory Balancing Accounts Receivable
Public Utility, Property, Plant and Equipment [Line Items]
Total regulatory balancing accounts			127,000,000	127,000,000	$ 127,000,000	0
Five Year Historical Period
Public Utility, Property, Plant and Equipment [Line Items]
Historical data period					5 years
Average annual statewide claims or settlements			6,500,000,000	6,500,000,000	$ 6,500,000,000
Twelve Year Historical Period
Public Utility, Property, Plant and Equipment [Line Items]
Historical data period					12 years
Average annual statewide claims or settlements			2,900,000,000	2,900,000,000	$ 2,900,000,000
Wildfire Fund Asset
Public Utility, Property, Plant and Equipment [Line Items]
Finite-lived intangible asset, useful life					15 years
Noncurrent liabilities – other
Public Utility, Property, Plant and Equipment [Line Items]
Wildfire fund, noncurrent			1,100,000,000	1,100,000,000	$ 1,100,000,000
Other noncurrent assets – other \| 2021 Dixie fire
Public Utility, Property, Plant and Equipment [Line Items]
Insurance receivable			150,000,000	150,000,000	150,000,000
Recovery Bonds \| Senior Secured Superpriority Debt
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount			$ 860,000,000	$ 860,000,000	$ 860,000,000	0		$ 860,000,000
Recovery Bonds \| Senior Secured Superpriority Debt \| Tranche One
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount								$ 266,000,000
Interest rate								1.46%
Recovery Bonds \| Senior Secured Superpriority Debt \| Tranche Two
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount								$ 160,000,000
Interest rate								2.28%
Recovery Bonds \| Senior Secured Superpriority Debt \| Tranche Three
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount								$ 434,000,000
Interest rate								2.82%
Recovery Bonds \| Minimum \| Senior Secured Superpriority Debt
Public Utility, Property, Plant and Equipment [Line Items]
Interest rate			1.46%	1.46%	1.46%
Pacific Gas & Electric Co (Utility)
Public Utility, Property, Plant and Equipment [Line Items]
Regulatory balancing accounts			$ 2,999,000,000	$ 2,999,000,000	$ 2,999,000,000	$ 2,001,000,000
Composite depreciation rate					3.82%	3.76%	3.80%
AFUDC debt recorded					$ 56,000,000	$ 35,000,000	$ 55,000,000
AFUDC equity recorded					133,000,000	140,000,000	79,000,000
Nuclear decommissioning obligation accrued					3,900,000,000	5,100,000,000
Estimated cost recovery on spent nuclear fuel storage proceeding every year					7,600,000,000	10,600,000,000
Wildfire fund asset			461,000,000	461,000,000	461,000,000	464,000,000
Amortization and accretion					517,000,000	413,000,000	$ 0
Pacific Gas & Electric Co (Utility) \| SBA Communications Corporation \| Wireless Licenses
Public Utility, Property, Plant and Equipment [Line Items]
Duration of contract		100 years
Other tower, duration of contract		15 years
Proceeds from sale of transmission tower license		$ 946,000,000
Proceeds from sale of transmission tower license, closing	947,000,000
Proceeds from financing obligations	$ 370,000,000
Proceeds from contract liability		471,000,000
Proceeds from regulatory liabilities, noncurrent		$ 455,000,000
Pacific Gas & Electric Co (Utility) \| Effective Date Towers \| SBA Communications Corporation \| Wireless Licenses \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Number of electric transmission towers \| transmissionTower		700
Number of other electric transmission towers \| transmissionTower		28,000
Pacific Gas & Electric Co (Utility) \| Receivables Securitization Program
Public Utility, Property, Plant and Equipment [Line Items]
Aggregate maximum amount of loans made by lenders			1,000,000,000	1,000,000,000	1,000,000,000
Debt financial instrument			974,000,000	974,000,000	974,000,000	1,000,000,000
Long-term debt, gross			974,000,000	974,000,000	$ 974,000,000	1,000,000,000
Pacific Gas & Electric Co (Utility) \| Diablo Canyon
Public Utility, Property, Plant and Equipment [Line Items]
Number of generation facilities \| facility					2
Pacific Gas & Electric Co (Utility) \| Humboldt Bay
Public Utility, Property, Plant and Equipment [Line Items]
Number of generation facilities \| numberOfFatality					1
PG&E AR Facility, LLC (SPV) \| Receivables Securitization Program
Public Utility, Property, Plant and Equipment [Line Items]
Accounts receivable, net			$ 3,300,000,000	$ 3,300,000,000	$ 3,300,000,000	$ 2,600,000,000

SUMMARY OF SIGNIFICANT ACCOUN_5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Revenues Disaggregated by Type of Customer) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Abstract]
Total operating revenues	$ 20,642	$ 18,469	$ 17,129
Electric
Disaggregation of Revenue [Abstract]
Total operating revenues	15,131	13,858	12,740
Natural gas
Disaggregation of Revenue [Abstract]
Total operating revenues	5,511	4,611	4,389
Pacific Gas & Electric Co (Utility)
Disaggregation of Revenue [Abstract]
Total operating revenues	20,642	18,469	17,129
Pacific Gas & Electric Co (Utility) \| Electric
Disaggregation of Revenue [Abstract]
Total operating revenues	14,178	13,185
Regulatory balancing accounts	953	673
Total operating revenues	15,131	13,858	12,740
Pacific Gas & Electric Co (Utility) \| Electric \| Residential
Disaggregation of Revenue [Abstract]
Total operating revenues	6,089	5,523
Pacific Gas & Electric Co (Utility) \| Electric \| Commercial
Disaggregation of Revenue [Abstract]
Total operating revenues	5,042	4,722
Pacific Gas & Electric Co (Utility) \| Electric \| Industrial
Disaggregation of Revenue [Abstract]
Total operating revenues	1,493	1,530
Pacific Gas & Electric Co (Utility) \| Electric \| Agricultural
Disaggregation of Revenue [Abstract]
Total operating revenues	1,565	1,471
Pacific Gas & Electric Co (Utility) \| Electric \| Public street and highway lighting
Disaggregation of Revenue [Abstract]
Total operating revenues	73	69
Pacific Gas & Electric Co (Utility) \| Electric \| Other
Disaggregation of Revenue [Abstract]
Total operating revenues	(84)	(130)
Pacific Gas & Electric Co (Utility) \| Natural gas
Disaggregation of Revenue [Abstract]
Total operating revenues	4,958	4,386
Regulatory balancing accounts	553	225
Total operating revenues	5,511	4,611	$ 4,389
Pacific Gas & Electric Co (Utility) \| Natural gas \| Residential
Disaggregation of Revenue [Abstract]
Total operating revenues	2,759	2,517
Pacific Gas & Electric Co (Utility) \| Natural gas \| Commercial
Disaggregation of Revenue [Abstract]
Total operating revenues	713	597
Pacific Gas & Electric Co (Utility) \| Natural gas \| Transportation service only
Disaggregation of Revenue [Abstract]
Total operating revenues	1,346	1,211
Pacific Gas & Electric Co (Utility) \| Natural gas \| Other
Disaggregation of Revenue [Abstract]
Total operating revenues	$ 140	$ 61

SUMMARY OF SIGNIFICANT ACCOUN_6

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Schedule of Estimated Useful Lives and Balances of Utilities Property, Plant and Equipment) (Details) - Pacific Gas & Electric Co (Utility) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 98,959	$ 93,892
Accumulated depreciation	(29,131)	(27,756)
Net property, plant, and equipment	69,828	66,136
Electricity generating facilities
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	11,217	12,505
Electricity generating facilities \| Northern California Wildfire
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 850
Electricity generating facilities \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	5 years
Electricity generating facilities \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	75 years
Electricity distribution facilities
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 37,723	34,902
Electricity distribution facilities \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	10 years
Electricity distribution facilities \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	70 years
Electricity transmission facilities
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 15,516	14,414
Electricity transmission facilities \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	15 years
Electricity transmission facilities \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	75 years
Natural gas distribution facilities
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 14,100	12,962
Natural gas distribution facilities \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	20 years
Natural gas distribution facilities \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	60 years
Natural gas transmission and storage facilities
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 9,067	8,293
Natural gas transmission and storage facilities \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	5 years
Natural gas transmission and storage facilities \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	66 years
Financing lease
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 18	18
Construction work in progress
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	3,480	2,757
General plant and other
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 7,838	$ 8,041
General plant and other \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	5 years
General plant and other \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	50 years

SUMMARY OF SIGNIFICANT ACCOUN_7

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Schedule of Changes in Asset Retirement Obligations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO liability at beginning of year	$ 6,412	$ 5,854
Liabilities incurred in the current period	0	268
Revision in estimated cash flows	(1,378)	53
Accretion	287	265
Liabilities settled	(23)	(28)
ARO liability at end of year	$ 5,298	$ 6,412

SUMMARY OF SIGNIFICANT ACCOUN_8

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Reclassifications Out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Accumulated Other Comprehensive Income (Loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	$ (22)	$ (5)
Net current period other comprehensive income	7	(17)
Ending balance	(15)	(22)
Accumulated Other Comprehensive Income (Loss) \| Pension Plan
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(39)	(22)
Net current period other comprehensive income	6	(17)
Ending balance	(33)	(39)
Accumulated Other Comprehensive Income (Loss) \| PBOP Plans
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	17	17
Net current period other comprehensive income	1	0
Ending balance	18	17
Amortization of prior service cost
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income:	6	6
Amortization of prior service cost \| Pension Plan
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income:	(4)	(4)
Amounts reclassified from other comprehensive income, tax	2	2
Amortization of prior service cost \| PBOP Plans
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income:	10	10
Amounts reclassified from other comprehensive income, tax	4	4
Amortization of net actuarial gain (loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications:	1,144	(247)
Amounts reclassified from other comprehensive income:	(20)	(13)
Amortization of net actuarial gain (loss) \| Pension Plan
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications:	1,007	(417)
Amounts reclassified from other comprehensive income:	4	2
Other comprehensive income before reclassifications, tax	391	162
Amounts reclassified from other comprehensive income, tax	2	1
Amortization of net actuarial gain (loss) \| PBOP Plans
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications:	137	170
Amounts reclassified from other comprehensive income:	(24)	(15)
Other comprehensive income before reclassifications, tax	53	66
Amounts reclassified from other comprehensive income, tax	9	6
Regulatory account transfer
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications:	(1,139)	230
Amounts reclassified from other comprehensive income:	16	7
Regulatory account transfer \| Pension Plan
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications:	(1,003)	400
Amounts reclassified from other comprehensive income:	2	2
Other comprehensive income before reclassifications, tax	390	155
Amounts reclassified from other comprehensive income, tax	1	1
Regulatory account transfer \| PBOP Plans
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications:	(136)	(170)
Amounts reclassified from other comprehensive income:	14	5
Other comprehensive income before reclassifications, tax	53	66
Amounts reclassified from other comprehensive income, tax	$ 5	$ 2

SUMMARY OF SIGNIFICANT ACCOUN_9

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Schedule of Lease Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Accounting Policies [Abstract]
Operating lease fixed cost	$ 578	$ 679
Operating lease variable cost	1,782	1,852
Total operating lease costs	$ 2,360	$ 2,531

SUMMARY OF SIGNIFICANT ACCOU_10

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Future Expected Operating Lease Payments) (Details) $ in Millions	Dec. 31, 2021USD ($)
Future Expected Operating Lease Payments
2022	$ 533
2023	276
2024	118
2025	111
2026	105
Thereafter	444
Total lease payments	1,587
Less imputed interest	(310)
Total	$ 1,277

REGULATORY ASSETS, LIABILITIE_3

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Assets) (Details) - USD ($) $ in Millions	10 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 9,207	$ 9,207	$ 8,978
Utility retained generation asset costs	1,200	1,200
Pension benefits
Regulatory Assets [Line Items]
Total long-term regulatory assets	708	708	2,245
Environmental compliance costs
Regulatory Assets [Line Items]
Total long-term regulatory assets	1,089	$ 1,089	1,112
Recovery Period		32 years
Utility retained generation
Regulatory Assets [Line Items]
Total long-term regulatory assets	133	$ 133	181
Recovery Period		6 years
Price risk management
Regulatory Assets [Line Items]
Total long-term regulatory assets	216	$ 216	204
Recovery Period		19 years
Unamortized loss, net of gain, on reacquired debt
Regulatory Assets [Line Items]
Total long-term regulatory assets	37	$ 37	49
Recovery Period		23 years
Catastrophic event memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	1,119	$ 1,119	842
Catastrophic event memorandum account \| COVID-19
Regulatory Assets [Line Items]
Total long-term regulatory assets	49	$ 49	49
Catastrophic event memorandum account \| Minimum
Regulatory Assets [Line Items]
Recovery Period		1 year
Catastrophic event memorandum account \| Maximum
Regulatory Assets [Line Items]
Recovery Period		3 years
Wildfire expense memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	347	$ 347	400
Fire hazard prevention memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	75	$ 75	137
Fire hazard prevention memorandum account \| Minimum
Regulatory Assets [Line Items]
Recovery Period		1 year
Fire hazard prevention memorandum account \| Maximum
Regulatory Assets [Line Items]
Recovery Period		3 years
Fire risk mitigation memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	44	$ 44	66
Fire risk mitigation memorandum account \| Minimum
Regulatory Assets [Line Items]
Recovery Period		1 year
Fire risk mitigation memorandum account \| Maximum
Regulatory Assets [Line Items]
Recovery Period		3 years
Wildfire mitigation plan memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	424	$ 424	390
Wildfire mitigation plan memorandum account \| Minimum
Regulatory Assets [Line Items]
Recovery Period		1 year
Wildfire mitigation plan memorandum account \| Maximum
Regulatory Assets [Line Items]
Recovery Period		3 years
Deferred income tax
Regulatory Assets [Line Items]
Total long-term regulatory assets	1,849	$ 1,849	908
Recovery Period		51 years
Insurance premium costs
Regulatory Assets [Line Items]
Total long-term regulatory assets	207	$ 207	294
Insurance premium costs \| Minimum
Regulatory Assets [Line Items]
Recovery Period		3 years
Insurance premium costs \| Maximum
Regulatory Assets [Line Items]
Recovery Period		4 years
Wildfire mitigation balancing account
Regulatory Assets [Line Items]
Total long-term regulatory assets	273	$ 273	156
Wildfire mitigation balancing account \| Minimum
Regulatory Assets [Line Items]
Recovery Period		1 year
Cost percentage threshold requiring approval		115.00%
Wildfire mitigation balancing account \| Maximum
Regulatory Assets [Line Items]
Recovery Period		3 years
General rate case memorandum accounts
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 0	$ 0	376
Recovery period	22 months
General rate case memorandum accounts \| Minimum
Regulatory Assets [Line Items]
Recovery Period		1 year
General rate case memorandum accounts \| Maximum
Regulatory Assets [Line Items]
Recovery Period		2 years
Vegetation management balancing account
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 1,411	$ 1,411	592
Vegetation management balancing account \| Minimum
Regulatory Assets [Line Items]
Recovery Period		1 year
Cost percentage threshold requiring approval		120.00%
Vegetation management balancing account \| Maximum
Regulatory Assets [Line Items]
Recovery Period		3 years
COVID-19 Pandemic protection memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	49	$ 49	84
COVID-19 pandemic protection memorandum account, undercollection bad debt
Regulatory Assets [Line Items]
Total long-term regulatory assets	30	30
COVID-19 pandemic protection memorandum account, program and accounts receivable financing costs
Regulatory Assets [Line Items]
Total long-term regulatory assets	19	19
Other
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 1,226	$ 1,226	$ 942

REGULATORY ASSETS, LIABILITIE_4

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Liabilities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 11,999	$ 10,424
Proceeds received from sale of transmission tower wireless licenses, refunded to customers	446
Federal Energy Regulatory Commission
Regulatory Liabilities [Line Items]
Proceeds received from sale of transmission tower wireless licenses, refunded to customers	311
California Public Utilities Commission
Regulatory Liabilities [Line Items]
Proceeds received from sale of transmission tower wireless licenses, refunded to customers	135
Cost of removal obligations
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	7,306	6,905
Recoveries in excess of AROs
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	388	458
Public purpose programs
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	946	948
Employee benefit plans
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	1,229	995
Transmission tower wireless licenses
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	446	0
SFGO sale
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	343	0
Other
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 1,341	$ 1,118

REGULATORY ASSETS, LIABILITIE_5

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Current Regulatory Balancing Accounts, Net) (Details) - USD ($) $ in Millions	Oct. 21, 2021	Dec. 31, 2021	Dec. 31, 2020
Regulatory Liabilities [Line Items]
Regulatory balancing accounts		$ 496	$ 410
Regulatory Balancing Accounts Payable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		1,121	1,245
Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		2,999	2,001
Electric distribution \| Regulatory Balancing Accounts Payable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		121	55
Electric transmission \| Regulatory Balancing Accounts Payable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		24	267
Gas distribution and transmission \| Regulatory Balancing Accounts Payable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		83	76
Gas distribution and transmission \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		0	102
Energy procurement \| Regulatory Balancing Accounts Payable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		211	158
Energy procurement \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		310	413
Public purpose programs \| Regulatory Balancing Accounts Payable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		259	410
Public purpose programs \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		321	292
Fire hazard prevention memorandum account \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		50	121
Fire risk mitigation memorandum account \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		14	33
Wildfire mitigation plan memorandum account \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		67	161
Wildfire mitigation balancing account \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		91	27
General rate case memorandum accounts \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		468	313
Vegetation management balancing account \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		127	115
Insurance premium costs
Regulatory Liabilities [Line Items]
Regulatory balancing accounts		82
Settlement recovery amount	$ 445.5
Insurance premium costs \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		605	135
Wildfire expense memorandum account \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		440	0
Residential uncollectibles balancing accounts \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		127	0
Nuclear decommissioning adjustment mechanism \| Regulatory Balancing Accounts Payable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		137	0
Other \| Regulatory Balancing Accounts Payable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		286	279
Other \| Regulatory Balancing Accounts Receivable
Regulatory Liabilities [Line Items]
Total regulatory balancing accounts		$ 379	$ 289

DEBT (Outstanding Borrowings an

DEBT (Outstanding Borrowings and Availability) (Details) - USD ($)	Feb. 08, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jun. 22, 2021	Jul. 01, 2020
Debt [Line Items]
Repayments of long term debt		$ 87,000,000	$ 764,000,000	$ 0
PG&E Corporation
Debt [Line Items]
Repayments of long term debt		28,000,000	664,000,000	0
Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Repayments of long term debt		59,000,000	100,000,000	$ 0
Revolving Credit Facility
Debt [Line Items]
Line of credit facility, maximum borrowing capacity		6,941,000,000
Loans Outstanding		4,300,000,000
Letters of Credit Outstanding		692,000,000
Facility Availability		1,923,000,000
Revolving Credit Facility \| PG&E Corporation
Debt [Line Items]
Line of credit facility, maximum borrowing capacity		500,000,000				$ 500,000,000
Loans Outstanding		0
Letters of Credit Outstanding		0
Facility Availability		500,000,000
Revolving Credit Facility \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Line of credit facility, maximum borrowing capacity		4,000,000,000			$ 4,000,000,000	$ 3,500,000,000
Loans Outstanding		1,885,000,000
Letters of Credit Outstanding		692,000,000
Facility Availability		1,423,000,000
Letter of credit sublimit		1,500,000,000
Term Loan \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Line of credit facility, maximum borrowing capacity		1,441,000,000
Loans Outstanding		1,441,000,000
Letters of Credit Outstanding		0
Facility Availability		0
Term Loan \| Pacific Gas & Electric Co (Utility) \| Subsequent Event
Debt [Line Items]
Repayments of long term debt	$ 142,500,000
Receivables Securitization Program \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Line of credit facility, maximum borrowing capacity		1,000,000,000
Loans Outstanding		974,000,000	$ 1,000,000,000
Letters of Credit Outstanding		0
Facility Availability		$ 0

DEBT (Narrative) (Details)

Feb. 08, 2022USD ($)

Nov. 15, 2021USD ($)

Aug. 11, 2021USD ($)

Jun. 24, 2021USD ($)

Jul. 01, 2020USD ($)numberOfClaimHoldernumberOfExtensionOption

Mar. 31, 2021USD ($)

Dec. 31, 2021USD ($)

Dec. 31, 2020USD ($)

Dec. 31, 2019USD ($)

Nov. 12, 2021USD ($)

Jun. 30, 2021USD ($)

Jun. 22, 2021USD ($)

Apr. 23, 2021USD ($)

Feb. 24, 2021USD ($)

Apr. 30, 2020USD ($)

Debt [Line Items]

Repayments of long term debt

$ 87,000,000

$ 764,000,000

$ 0

Intercompany note to PG&E Corporation

$ 145,000,000

2017 Northern California wildfires

Debt [Line Items]

Customer Harm Threshold, post-emergence transaction, securitized

$ 7,500,000,000

Customer Harm Threshold, post-emergence transaction, debt retirement

$ 6,000,000,000

2017 Northern California wildfires | Fire Risk Mitigation Capital Expenditures

Debt [Line Items]

Customer Harm Threshold, post-emergence transaction, securitized

$ 1,190,000,000

PG&E Corporation

Debt [Line Items]

Repayments of long term debt

28,000,000

664,000,000

Intercompany note to PG&E Corporation

(145,000,000)

Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Repayments of long term debt

59,000,000

100,000,000

Intercompany note to PG&E Corporation

145,000,000

$ 0

Revolving Credit Facility

Debt [Line Items]

Line of credit facility, maximum borrowing capacity

6,941,000,000

Revolving Credit Facility | PG&E Corporation

Debt [Line Items]

Line of credit facility, maximum borrowing capacity

$ 500,000,000

500,000,000

Debt, number of extension options | numberOfExtensionOption

Debt instrument, extension option, term

1 year

Revolving Credit Facility | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Line of credit facility, maximum borrowing capacity

$ 3,500,000,000

4,000,000,000

$ 4,000,000,000

Debt, number of extension options | numberOfClaimHolder

Debt instrument, extension option, term

1 year

Repayments of debt

$ 300,000,000

Term Loan Credit Facility | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Line of credit facility, maximum borrowing capacity

$ 3,000,000,000

364-Day Term Loan Facility | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Line of credit facility, maximum borrowing capacity

$ 1,500,000,000

Debt instrument, term

364 days

Repayments of debt

$ 1,500,000,000

18-Month Term Loan Facility | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Line of credit facility, maximum borrowing capacity

$ 1,500,000,000

Debt instrument, term

18 months

Intercompany Loan

Debt [Line Items]

Debt instrument, term

364 days

Recovery Bonds | Senior Secured Superpriority Debt

Debt [Line Items]

Debt instrument, face amount

860,000,000

$ 0

$ 860,000,000

Recovery Bonds | Senior Secured Superpriority Debt | Tranche One

Debt [Line Items]

Debt instrument, face amount

$ 266,000,000

Interest rate

1.46%

Recovery Bonds | Senior Secured Superpriority Debt | Tranche Two

Debt [Line Items]

Debt instrument, face amount

$ 160,000,000

Interest rate

2.28%

Recovery Bonds | Senior Secured Superpriority Debt | Tranche Three

Debt [Line Items]

Debt instrument, face amount

$ 434,000,000

Interest rate

2.82%

Recovery Bonds | 2017 Northern California wildfires | Fire Risk Mitigation Capital Expenditures

Debt [Line Items]

Proceeds from issuance of debt

1,200,000,000

Debt issuance costs

$ 13,300,000

First Mortgage Bonds, Exchange Stated Maturity 2023 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Debt instrument, face amount

$ 1,500,000,000

Interest rate

1.367%

First Mortgage Bonds, Exchange Stated Maturity 2031 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Debt instrument, face amount

$ 450,000,000

Interest rate

3.25%

First Mortgage Bonds, Exchange Stated Maturity 2041 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Debt instrument, face amount

$ 450,000,000

Interest rate

4.20%

First Mortgage Bonds, Exchange Stated Maturity 2028

Debt [Line Items]

Debt instrument, face amount

$ 800,000,000

Interest rate

3.00%

First Mortgage Bonds, Variable, Stated Maturity 2022 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Debt instrument, face amount

300,000,000

First Mortgage Bonds due November 15, 2021 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Repayments of debt

1,450,000,000

First Mortgage Bonds, Stated Maturity 2023 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Debt instrument, face amount

$ 900,000,000

Interest rate

1.70%

First Mortgage Bonds, Stated Maturity 2031 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Debt instrument, face amount

$ 550,000,000

Interest rate

3.25%

Term Loan | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Line of credit facility, maximum borrowing capacity

$ 1,441,000,000

Term Loan | Pacific Gas & Electric Co (Utility) | Subsequent Event

Debt [Line Items]

Repayments of long term debt

$ 142,500,000

DEBT (Schedule of Long-term Deb

DEBT (Schedule of Long-term Debt) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Nov. 15, 2021	Nov. 12, 2021	Dec. 31, 2020
Debt [Line Items]
Less: current portion, net of debt issuance costs	$ (4,481)			$ (28)
Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Less: current portion, net of debt issuance costs	(4,455)			0
PG&E Corporation
Debt [Line Items]
Less: current portion, net of debt issuance costs	(27)			(28)
New Debt
Debt [Line Items]
Long-term debt, net	38,225			37,288
New Debt \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Less: current portion, net of debt issuance costs	(1,441)			0
Unamortized discount, net of premium and debt issuance costs	0			(6)
Long-term debt, net	33,632			32,664
New Debt \| PG&E Corporation
Debt [Line Items]
Less: current portion, net of debt issuance costs	(26)			0
Unamortized discount, net of premium and debt issuance costs	(90)			(85)
Long-term debt, net	4,593			4,624
Term Loan, Stated Maturity 2025 \| PG&E Corporation
Debt [Line Items]
Long-term debt, gross	$ 2,709			$ 2,709
Term Loan, Stated Maturity 2025 \| PG&E Corporation \| LIBOR
Debt [Line Items]
Stated interest rate	3.50%			5.50%
Senior Notes Due 2028 \| PG&E Corporation
Debt [Line Items]
Stated interest rate	5.00%
Long-term debt, gross	$ 1,000			$ 1,000
Senior Notes Due 2030 \| PG&E Corporation
Debt [Line Items]
Stated interest rate	5.25%
Long-term debt, gross	$ 1,000			1,000
First Mortgage Bonds \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Less: current portion, net of debt issuance costs	(2,996)			0
Unamortized discount, net of premium and debt issuance costs	(190)			(182)
Long-term debt, net	31,816			30,170
First Mortgage Bonds, Variable, Stated Maturity 2022 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 500			$ 500
Recovery Bonds		$ 300
First Mortgage Bonds, Variable, Stated Maturity 2022 \| Pacific Gas & Electric Co (Utility) \| LIBOR
Debt [Line Items]
Stated interest rate	1.69%			1.70%
First Mortgage Bonds, Stated Maturity 2022 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate	1.75%
Long-term debt, gross	$ 2,500			$ 2,500
First Mortgage Bonds, Stated Maturity 2023 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate		1.70%
Long-term debt, gross	$ 3,575			1,175
Recovery Bonds		$ 900
First Mortgage Bonds, Stated Maturity 2023 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	1.37%
First Mortgage Bonds, Stated Maturity 2023 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.25%
First Mortgage Bonds, Stated Maturity 2024 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 800			800
First Mortgage Bonds, Stated Maturity 2024 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	3.40%
First Mortgage Bonds, Stated Maturity 2024 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	3.75%
First Mortgage Bonds, Stated Maturity 2025 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 1,475			1,475
First Mortgage Bonds, Stated Maturity 2025 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	3.45%
First Mortgage Bonds, Stated Maturity 2025 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	3.50%
First Mortgage Bonds, Stated Maturity 2026 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 2,551			2,551
First Mortgage Bonds, Stated Maturity 2026 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	2.95%
First Mortgage Bonds, Stated Maturity 2026 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	3.15%
First Mortgage Bonds, Stated Maturity 2027 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 2,550			2,550
First Mortgage Bonds, Stated Maturity 2027 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	2.10%
First Mortgage Bonds, Stated Maturity 2027 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	3.30%
First Mortgage Bonds, Stated Maturity 2028 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 1,975			1,175
First Mortgage Bonds, Stated Maturity 2028 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	3.00%
First Mortgage Bonds, Stated Maturity 2028 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.65%
First Mortgage Bonds, Stated Maturity 2030 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 3,100			3,100
First Mortgage Bonds, Stated Maturity 2030 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.55%
First Mortgage Bonds, Stated Maturity 2031 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate		3.25%
Long-term debt, gross	$ 3,000			2,000
Recovery Bonds		$ 550
First Mortgage Bonds, Stated Maturity 2031 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	2.50%
First Mortgage Bonds, Stated Maturity 2031 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	3.25%
First Mortgage Bonds, Stated Maturity 2040 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 2,951			2,951
First Mortgage Bonds, Stated Maturity 2040 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	3.30%
First Mortgage Bonds, Stated Maturity 2040 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.50%
First Mortgage Bonds, Stated Maturity 2041 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 700			250
First Mortgage Bonds, Stated Maturity 2041 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	4.20%
First Mortgage Bonds, Stated Maturity 2041 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.50%
First Mortgage Bonds, Stated Maturity 2042 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 750			750
First Mortgage Bonds, Stated Maturity 2042 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	3.75%
First Mortgage Bonds, Stated Maturity 2042 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.45%
First Mortgage Bonds, Stated Maturity 2043 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate	4.60%
Long-term debt, gross	$ 375			375
First Mortgage Bonds, Stated Maturity 2044 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate	4.75%
Long-term debt, gross	$ 675			675
First Mortgage Bonds, Stated Maturity 2045 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate	4.30%
Long-term debt, gross	$ 600			600
First Mortgage Bonds, Stated Maturity 2046 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 1,050			1,050
First Mortgage Bonds, Stated Maturity 2046 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	4.00%
First Mortgage Bonds, Stated Maturity 2046 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.25%
First Mortgage Bonds, Stated Maturity 2047 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate	3.95%
Long-term debt, gross	$ 850			850
First Mortgage Bonds, Stated Maturity 2050 \| Minimum
Debt [Line Items]
Stated interest rate	3.50%
First Mortgage Bonds, Stated Maturity 2050 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 5,025			5,025
First Mortgage Bonds, Stated Maturity 2050 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.95%
Recovery Bonds \| Senior Secured Superpriority Debt
Debt [Line Items]
Less: current portion, net of debt issuance costs	$ (18)			0
Recovery Bonds	$ 860		$ 860	0
Recovery Bonds \| Minimum \| Senior Secured Superpriority Debt
Debt [Line Items]
Stated interest rate	1.46%
Recovery Bonds \| Maximum \| Senior Secured Superpriority Debt
Debt [Line Items]
Stated interest rate	2.82%
Receivables Securitization Program \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 974			1,000
Long-term debt, net	$ 974			$ 1,000
Receivables Securitization Program \| Pacific Gas & Electric Co (Utility) \| LIBOR
Debt [Line Items]
Debt, average interest rate	1.30%			1.57%
18-Months Term Loan \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
18-month Term Loan - Stated Maturity: 2022	$ 1,441			$ 1,500
18-Months Term Loan \| Pacific Gas & Electric Co (Utility) \| LIBOR
Debt [Line Items]
Stated interest rate	2.38%			2.44%
Debt, average interest rate

DEBT (Schedule of Contractual R

DEBT (Schedule of Contractual Repayment Schedule) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Debt [Line Items]
Total consolidated debt	$ 42,126
Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	3.49%
Fixed rate obligations	$ 34,502
Variable rate obligations	$ 2,915
Pacific Gas & Electric Co (Utility) \| 18-Months Term Loan
Debt [Line Items]
Debt Instrument, term	18 months
Pacific Gas & Electric Co (Utility) \| 18-Months Term Loan \| LIBOR
Debt [Line Items]
Debt, average interest rate
Pacific Gas & Electric Co (Utility) \| Receivables Securitization Program \| LIBOR
Debt [Line Items]
Debt, average interest rate	1.30%	1.57%
PG&E Corporation
Debt [Line Items]
Average fixed interest rate	5.13%
Fixed rate obligations	$ 2,000
Variable interest rate as of December 31, 2021	3.50%
Variable rate obligations	$ 2,709
2022
Debt [Line Items]
Total consolidated debt	$ 4,469
2022 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	1.75%
Fixed rate obligations	$ 2,500
Variable interest rate as of December 31, 2021	2.20%
Variable rate obligations	$ 1,941
2022 \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	0.00%
Fixed rate obligations	$ 0
Variable interest rate as of December 31, 2021	3.50%
Variable rate obligations	$ 28
2023
Debt [Line Items]
Total consolidated debt	$ 4,577
2023 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	2.26%
Fixed rate obligations	$ 3,575
Variable rate obligations	$ 974
2023 \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	0.00%
Fixed rate obligations	$ 0
Variable interest rate as of December 31, 2021	3.50%
Variable rate obligations	$ 28
2024
Debt [Line Items]
Total consolidated debt	$ 828
2024 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	3.60%
Fixed rate obligations	$ 800
Variable interest rate as of December 31, 2021	0.00%
Variable rate obligations	$ 0
2024 \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	0.00%
Fixed rate obligations	$ 0
Variable interest rate as of December 31, 2021	3.50%
Variable rate obligations	$ 28
2025
Debt [Line Items]
Total consolidated debt	$ 4,100
2025 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	3.47%
Fixed rate obligations	$ 1,475
Variable interest rate as of December 31, 2021	0.00%
Variable rate obligations	$ 0
2025 \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	0.00%
Fixed rate obligations	$ 0
Variable interest rate as of December 31, 2021	3.50%
Variable rate obligations	$ 2,625
2026
Debt [Line Items]
Total consolidated debt	$ 2,551
2026 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	3.10%
Fixed rate obligations	$ 2,551
Variable interest rate as of December 31, 2021	0.00%
Variable rate obligations	$ 0
2026 \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	0.00%
Fixed rate obligations	$ 0
Variable interest rate as of December 31, 2021	0.00%
Variable rate obligations	$ 0
Thereafter
Debt [Line Items]
Total consolidated debt	$ 25,601
Thereafter \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	3.90%
Fixed rate obligations	$ 23,601
Variable interest rate as of December 31, 2021	0.00%
Variable rate obligations	$ 0
Thereafter \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	5.13%
Fixed rate obligations	$ 2,000
Variable interest rate as of December 31, 2021	0.00%
Variable rate obligations	$ 0

COMMON STOCK AND SHARE-BASED _3

COMMON STOCK AND SHARE-BASED COMPENSATION (Narrative) (Details)

Feb. 08, 2022USD ($)

Jan. 31, 2022USD ($)shares

Dec. 31, 2021USD ($)shares

Jul. 09, 2021USD ($)shares

May 28, 2020

Dec. 31, 2021USD ($)$ / sharesshares

Dec. 31, 2020USD ($)$ / sharesshares

Dec. 31, 2019USD ($)$ / shares

Dec. 31, 2021USD ($)shares

Feb. 04, 2022shares

Jul. 08, 2021

Apr. 30, 2021USD ($)

Jul. 01, 2020

Mar. 20, 2020USD ($)

Schedule of Capitalization, Equity [Line Items]

Common stock, shares outstanding (in shares)

1,985,400,540

1,984,678,673

1,985,400,540

Treasury stock, shares at cost (in shares)

477,743,590

Shares outstanding (in shares)

2,463,891,104

Common stock, shares issued, reserve, additional shares due to nonconforming new shares (in shares)

Dividend reinstatement target, amount | $

$ 6,200,000,000

Equity capital structure percentage

52.00%

Equity capital structure, waiver period

5 years

Shares available for LTIP award (in shares)

58,552,722

Weighted average grant date fair value of granted shares (in dollars per share) | $ / shares

$ 11.01

$ 9.25

$ 18.57

Total fair value | $

$ 19,000,000

$ 31,000,000

$ 42,000,000

Total unrecognized compensation costs | $

$ 81,000,000

Remaining weighted average period

2 years 2 months 8 days

Subsequent Event

Schedule of Capitalization, Equity [Line Items]

Shares outstanding (in shares)

2,463,891,104

Common stock, shares outstanding, adjusted (in shares)

1,548,403,924

Percentage stock ownership limitation

0.0298

Cumulative and unpaid dividends | $

$ 59,100,000

Preferred stock dividend requirement | $

$ 3,500,000

Fire Victim Trust | Subsequent Event

Schedule of Capitalization, Equity [Line Items]

Number of shares exchanged (in shares)

40,000,000

2014 LTIP, Amended

Schedule of Capitalization, Equity [Line Items]

Number of shares issued for LTIP, maximum (in shares)

91,000,000

Stock Options

Schedule of Capitalization, Equity [Line Items]

Granted (in shares)

Weighted-average period

1 year 5 months 19 days

Stock Options | 2014 LTIP

Schedule of Capitalization, Equity [Line Items]

Term of award

10 years

Award vesting period

3 years

Total unrecognized compensation costs | $

$ 0

Granted (in shares)

Restricted stock units

Schedule of Capitalization, Equity [Line Items]

Award vesting period

3 years

Tax detriment | $

$ 11,000,000

Performance shares

Schedule of Capitalization, Equity [Line Items]

Award vesting period

3 years

Tax detriment | $

$ 19,000,000

Industry performance period

3 years

Award grant date fair value recognition period

3 years

Performance shares granted (in dollars per share) | $ / shares

$ 11.83

$ 9.62

$ 15.39

Employee service share based compensation nonvested performance shares total compensation cost not yet recognized | $

$ 50,000,000

PG&E ShareCo | Common Stock

Schedule of Capitalization, Equity [Line Items]

Stock issued during period, shares, new issues (in shares)

477,743,590

PG&E ShareCo | Fire Victim Trust Share Exchange and Tax Matters Agreement | Common Stock

Schedule of Capitalization, Equity [Line Items]

Stock issued during period, shares, new issues (in shares)

477,743,590

Transfer of shares to Fire Victim Trust (in shares)

477,743,590

PG&E Corporation

Schedule of Capitalization, Equity [Line Items]

Increase in common stock | $

$ 4,850,000,000

PG&E Corporation | Equity Units

Schedule of Capitalization, Equity [Line Items]

Stock issued during period, shares, new issues (in shares)

16,000,000

PG&E Corporation | Minimum

Schedule of Capitalization, Equity [Line Items]

Percentage of equity security ownership with board of director approval

4.75%

PG&E Corporation | Minimum | Common Stock

Schedule of Capitalization, Equity [Line Items]

Amount of shares, right to receive

138,000,000

PG&E Corporation | Minimum | Revolving Credit Facility

Schedule of Capitalization, Equity [Line Items]

Debt, ratio of total consolidated debt to consolidated capitalization, loans outstanding balance

150.00%

Debt, ratio of total consolidated debt to consolidated capitalization, cash dividend declared

100.00%

PG&E Corporation | Maximum | Common Stock

Schedule of Capitalization, Equity [Line Items]

Amount of shares, right to receive

168,000,000

PG&E Corporation | Maximum | Revolving Credit Facility

Schedule of Capitalization, Equity [Line Items]

Debt, ratio of total consolidated debt to consolidated capitalization

70.00%

PG&E Corporation | Maximum | Fire Victim Trust Share Exchange and Tax Matters Agreement

Schedule of Capitalization, Equity [Line Items]

Common stock, shares authorized, reserve, additional shares due to nonconforming new shares (in shares)

250,000,000

PG&E Corporation | At The Market Equity Distribution Program | Common Stock

Schedule of Capitalization, Equity [Line Items]

Sale of stock, number of shares issued in transaction, amount | $

$ 400,000,000

COMMON STOCK AND SHARE-BASED _4

COMMON STOCK AND SHARE-BASED COMPENSATION (Long-term Incentive Plan) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense (pre-tax)	$ 56	$ 35	$ 50
Total compensation expense (after-tax)	40	25	35
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense (pre-tax)	0	3	7
Restricted stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense (pre-tax)	35	15	21
Performance shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense (pre-tax)	$ 21	$ 17	$ 22

COMMON STOCK AND SHARE-BASED _5

COMMON STOCK AND SHARE-BASED COMPENSATION (Summary of Stock Option Activity) (Details) - Stock Options - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Number of Stock Options
Granted (in shares)	0	0
2014 LTIP
Number of Stock Options
Outstanding, beginning of period (in shares)	2,221,247
Granted (in shares)	0
Exercised (in shares)	0
Forfeited or expired (in shares)	(25,413)
Outstanding, end of period (in shares)	2,195,834	2,221,247
Vested or expected to vest (in shares)	2,195,834
Exercisable (in shares)	2,195,834
Weighted Average Grant- Date Fair Value
Outstanding, beginning of period (in dollars per share)	$ 7.45
Forfeited or expired (in dollars per share)	10.23
Outstanding, end of period (in dollars per share)	7.42	$ 7.45
Vested or expected to vest (in dollars per share)	7.42
Exercisable (in dollars per share)	$ 7.42
Weighted Average Remaining Contractual Term
Outstanding	4 years 3 months 29 days
Expected to vest	4 years 3 months 29 days
Exercisable	4 years 3 months 29 days

COMMON STOCK AND SHARE-BASED _6

COMMON STOCK AND SHARE-BASED COMPENSATION (Restricted Stock Units) (Details) - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Number of Restricted Stock Units
Nonvested, beginning balance (in shares)	890,353
Granted (in shares)	10,352,117
Vested (in shares)	(743,672)
Forfeited (in shares)	(408,423)
Nonvested, ending balance (in shares)	10,090,375	890,353
Weighted Average Grant- Date Fair Value
Nonvested, beginning balance (in dollars per share)	$ 23.05
Granted (in dollars per share)	11.01	$ 9.25	$ 18.57
Vested (in dollars per share)	25.20
Forfeited (in dollars per share)	11.67
Nonvested, ending balance (in dollars per share)	$ 11	$ 23.05

COMMON STOCK AND SHARE-BASED _7

COMMON STOCK AND SHARE-BASED COMPENSATION (Performance Shares) (Details) - Performance shares - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Number of Performance Shares
Nonvested , beginning balance (in shares)	7,288,782
Granted (in shares)	2,714,645
Vested (in shares)	0
Forfeited (in shares)	(1,436,418)
Nonvested, ending balance (in shares)	8,567,009	7,288,782
Weighted Average Grant- Date Fair Value
Nonvested, beginning balance (in dollars per share)	$ 9.16
Granted (in dollars per share)	11.83	$ 9.62	$ 15.39
Vested (in dollars per share)	0
Forfeited (in dollars per share)	11.35
Nonvested, ending balance (in dollars per share)	9.64	$ 9.16
Expirations, fair value (in dollars per share)	$ 0

PREFERRED STOCK (Narrative) (De

PREFERRED STOCK (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Feb. 08, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jan. 31, 2022
Subsequent Event
Preferred Stock [Line Items]
Cumulative and unpaid dividends					$ 59.1
Preferred stock dividend requirement	$ 3.5
Pacific Gas & Electric Co (Utility)
Preferred Stock [Line Items]
Preferred stock dividend requirement		$ 14	$ 14	$ 14
Pacific Gas & Electric Co (Utility) \| Minimum
Preferred Stock [Line Items]
Redemption price (in dollars per share)		$ 25.75	$ 25.75
Pacific Gas & Electric Co (Utility) \| Maximum
Preferred Stock [Line Items]
Redemption price (in dollars per share)		$ 27.25	$ 27.25
Pacific Gas & Electric Co (Utility) \| Nonredeemable Preferred Stock
Preferred Stock [Line Items]
Nonredeemable preferred stock outstanding		$ 145	$ 145
Preferred stock dividends per share, low range (in dollars per share)		$ 1.25
Preferred stock dividends per share, high range (in dollars per share)		$ 1.50
Pacific Gas & Electric Co (Utility) \| Nonredeemable Preferred Stock \| Minimum
Preferred Stock [Line Items]
Preferred stock interest rate		5.00%	5.00%
Pacific Gas & Electric Co (Utility) \| Nonredeemable Preferred Stock \| Maximum
Preferred Stock [Line Items]
Preferred stock interest rate		6.00%	6.00%
Pacific Gas & Electric Co (Utility) \| Redeemable Preferred Stock
Preferred Stock [Line Items]
Redeemable preferred stock outstanding		$ 113	$ 113
Preferred stock dividends per share, low range (in dollars per share)		$ 1.09
Preferred stock dividends per share, high range (in dollars per share)		$ 1.25
Pacific Gas & Electric Co (Utility) \| Redeemable Preferred Stock \| Minimum
Preferred Stock [Line Items]
Preferred stock interest rate		4.36%	4.36%
Pacific Gas & Electric Co (Utility) \| Redeemable Preferred Stock \| Maximum
Preferred Stock [Line Items]
Preferred stock interest rate		5.00%	5.00%
PG&E Corporation
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)		400,000,000
Preferred stock, shares outstanding (in shares)		0
$25 Par Value \| Pacific Gas & Electric Co (Utility)
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)		75,000,000
Preferred stock, par value (in dollars per share)		$ 25
$100 Par Value \| Pacific Gas & Electric Co (Utility)
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)		10,000,000
Preferred stock, shares outstanding (in shares)		0
Preferred stock, par value (in dollars per share)		$ 100

EARNINGS PER SHARE (Reconciliat

EARNINGS PER SHARE (Reconciliation of PG&E Corporation's Income Available for Common Shareholders and Weighted Average Shares of Common Stock Outstanding for Calculating Diluted EPS) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share [Abstract]
Loss attributable to common shareholders	$ (102)	$ (1,318)	$ (7,656)
Weighted average common shares outstanding, basic (in shares)	1,985	1,257	528
Add incremental shares from assumed conversions:
Employee share-based compensation (in shares)	0	0	0
Equity Units (in shares)	0	0	0
Weighted average common share outstanding, diluted (in shares)	1,985	1,257	528
Total Loss per common share, diluted (in dollars per share)	$ (0.05)	$ (1.05)	$ (14.50)

INCOME TAXES (Schedule of Incom

INCOME TAXES (Schedule of Income Tax Provision (Benefit)) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current:
Federal	$ 0	$ (26)	$ 1
State	1	(34)	101
Deferred:
Federal	543	258	(2,361)
State	296	171	(1,136)
Tax credits	(4)	(7)	(5)
Income tax provision (benefit)	836	362	(3,400)
Pacific Gas & Electric Co (Utility)
Current:
Federal	0	(26)	4
State	0	(34)	94
Deferred:
Federal	588	290	(2,363)
State	316	185	(1,137)
Tax credits	(4)	(7)	(5)
Income tax provision (benefit)	$ 900	$ 408	$ (3,407)

INCOME TAXES (Schedule of Defer

INCOME TAXES (Schedule of Deferred Tax Assets and Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Pacific Gas & Electric Co (Utility)
Deferred income tax assets:
Tax carryforwards	$ 5,425	$ 7,529
Compensation	108	109
Wildfire-related claims	1,723	544
Operating lease liability	346	488
Transmission tower wireless licenses	266	0
Other	293	219
Total deferred income tax assets	8,161	8,889
Deferred income tax liabilities:
Property related basis differences	8,835	8,300
Regulatory balancing accounts	1,193	763
Debt financing costs	501	526
Operating lease right of use asset	346	488
Income tax regulatory asset	517	254
Other	178	128
Total deferred income tax liabilities	11,570	10,459
Total net deferred income tax liabilities	3,409	1,570
PG&E Corporation
Deferred income tax assets:
Tax carryforwards	5,628	7,641
Compensation	185	187
Wildfire-related claims	1,723	544
Operating lease liability	346	489
Transmission tower wireless licenses	266	0
Other	278	212
Total deferred income tax assets	8,426	9,073
Deferred income tax liabilities:
Property related basis differences	8,847	8,311
Regulatory balancing accounts	1,193	763
Debt financing costs	501	526
Operating lease right of use asset	346	489
Income tax regulatory asset	517	254
Other	199	128
Total deferred income tax liabilities	11,603	10,471
Total net deferred income tax liabilities	$ 3,177	$ 1,398

INCOME TAXES (Schedule of Effec

INCOME TAXES (Schedule of Effective Income Tax Rate Reconciliation) (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pacific Gas & Electric Co (Utility)
Operating Loss Carryforwards [Line Items]
Federal statutory income tax rate	21.00%	21.00%	21.00%
State income tax (net of federal benefit)	24.10%	19.10%	7.50%
Effect of regulatory treatment of fixed asset differences	(51.60%)	(44.90%)	2.80%
Tax credits	1.20%	1.70%	0.10%
Fire Victim Trust	0.919	0.517	0
Bankruptcy and emergence	0.00%	2.40%	0.00%
Other, net	2.60%	2.20%	(0.50%)
Effective tax rate	86.80%	49.80%	30.90%
PG&E Corporation
Operating Loss Carryforwards [Line Items]
Federal statutory income tax rate	21.00%	21.00%	21.00%
State income tax (net of federal benefit)	31.30%	(15.30%)	7.50%
Effect of regulatory treatment of fixed asset differences	(71.50%)	39.00%	2.80%
Tax credits	(1.70%)	1.50%	0.10%
Fire Victim Trust	1.273	(0.449)	0
Bankruptcy and emergence	0.00%	(37.60%)	0.00%
Other, net	5.30%	(2.10%)	(0.60%)
Effective tax rate	111.70%	(38.40%)	30.80%

INCOME TAXES (Schedule of Chang

INCOME TAXES (Schedule of Change in Unrecognized Tax Benefits) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pacific Gas & Electric Co (Utility)
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance, beginning of period	$ 437	$ 420	$ 377
Reductions for tax position taken during a prior year	(23)	(43)	(1)
Additions for tax position taken during the current year	85	60	44
Settlements	(1)	0	0
Balance, end of period	498	437	420
PG&E Corporation
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance, beginning of period	437	420	377
Reductions for tax position taken during a prior year	(23)	(43)	(1)
Additions for tax position taken during the current year	85	60	44
Settlements	(1)	0	0
Balance, end of period	$ 498	$ 437	$ 420

INCOME TAXES (Narrative) (Detai

INCOME TAXES (Narrative) (Details) - USD ($) shares in Millions, $ in Millions	Jan. 31, 2022	Feb. 25, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jul. 01, 2020
Investments, Owned, Federal Income Tax Note [Line Items]
Total UTB that, if recognized, would impact the effective income tax rate as of the end of the year			$ 30
Decrease in net operating loss			1,883	$ 1,755	$ (10,094)
Fire Victim Trust
Investments, Owned, Federal Income Tax Note [Line Items]
Cash contribution by company						$ 5,400
Stock contribution by company (in shares)						4,540
Decrease in net operating loss		$ 10,000
Payments made to Fire Victim Trust			$ 1,670
Decrease in net operating loss, tax		$ 1,300
Fire Victim Trust \| Subsequent Event
Investments, Owned, Federal Income Tax Note [Line Items]
Number of shares exchanged (in shares)	40

INCOME TAXES (Summary of Operat

INCOME TAXES (Summary of Operating Loss and Tax Credit Carryforward) (Details) $ in Millions	Dec. 31, 2021USD ($)
Federal
Operating Loss Carryforwards [Line Items]
Tax credit carryforward	$ 144
Federal \| Pre-2018
Operating Loss Carryforwards [Line Items]
Net operating loss carryforward	3,600
Federal \| Post-2017
Operating Loss Carryforwards [Line Items]
Net operating loss carryforward	17,467
State
Operating Loss Carryforwards [Line Items]
Net operating loss carryforward	18,853
Tax credit carryforward	$ 122

DERIVATIVES (Volumes of Outstan

DERIVATIVES (Volumes of Outstanding Derivative Contracts) (Details)	Dec. 31, 2021MMBTUMWh	Dec. 31, 2020MMBTUMWh
Forwards, Futures and Swaps \| Natural Gas (MMBtus)
Derivative [Line Items]
Contract Volume	173,361,635	146,642,863
Forwards, Futures and Swaps \| Electricity (Megawatt-hours)
Derivative [Line Items]
Contract Volume \| MWh	10,283,639	9,435,830
Options \| Natural Gas (MMBtus)
Derivative [Line Items]
Contract Volume	14,420,000	14,140,000
Options \| Electricity (Megawatt-hours)
Derivative [Line Items]
Contract Volume	288,000	0
Congestion revenue rights \| Electricity (Megawatt-hours)
Derivative [Line Items]
Contract Volume \| MWh	239,857,610	266,091,470

DERIVATIVES (Outstanding Deriva

DERIVATIVES (Outstanding Derivative Balances) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Derivatives And Hedging Activities [Line Items]
Netting	$ 143	$ 115
Netting	27	25
Commodity Contract \| Pacific Gas & Electric Co (Utility)
Derivatives And Hedging Activities [Line Items]
Netting	(42)	(73)
Netting	0	0
Cash Collateral	170	140
Total Derivative Balance	128	67
Commodity Contract \| Pacific Gas & Electric Co (Utility) \| Current assets – other
Derivatives And Hedging Activities [Line Items]
Netting	58	33
Netting	(9)	0
Cash Collateral	152	115
Total Derivative Balance	201	148
Commodity Contract \| Pacific Gas & Electric Co (Utility) \| Other noncurrent assets – other
Derivatives And Hedging Activities [Line Items]
Netting	169	136
Netting	0	0
Cash Collateral	0	0
Total Derivative Balance	169	136
Commodity Contract \| Pacific Gas & Electric Co (Utility) \| Current liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Balance	(53)	(38)
Netting	9	0
Cash Collateral	18	15
Total Derivative Balance	(26)	(23)
Commodity Contract \| Pacific Gas & Electric Co (Utility) \| Noncurrent liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Balance	(216)	(204)
Netting	0	0
Cash Collateral	0	10
Total Derivative Balance	$ (216)	$ (194)

FAIR VALUE MEASUREMENTS (Assets

FAIR VALUE MEASUREMENTS (Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Short-term investments	$ 289	$ 470
Total nuclear decommissioning trusts	4,581	4,209
Rabbi trusts	180	185
Long-term disability trust	138	167
Netting	143	115
TOTAL ASSETS	5,558	5,315
Netting	(27)	(25)
Amount primarily related to deferred taxes on appreciation of investment value	783	671
Electric
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Netting	6	2
Netting	(24)	(25)
Gas
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Netting	137	113
Netting	(3)	0
Short-term investments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	22	27
Long-term disability trust	6	9
Global equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	2,504	2,398
Fixed-income securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	2,024	1,759
Rabbi trusts	104	106
Price risk management instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	370	284
TOTAL LIABILITIES	242	217
Price risk management instruments \| Electric
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	229	170
TOTAL LIABILITIES	235	214
Price risk management instruments \| Gas
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	141	114
TOTAL LIABILITIES	7	3
Life insurance contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi trusts	76	79
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Short-term investments	289	470
Total nuclear decommissioning trusts	3,684	3,349
Rabbi trusts	0	0
Long-term disability trust	6	9
TOTAL ASSETS	3,979	3,828
Level 1 \| Short-term investments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	22	27
Long-term disability trust	6	9
Level 1 \| Global equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	2,504	2,398
Level 1 \| Fixed-income securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	1,158	924
Rabbi trusts	0	0
Level 1 \| Price risk management instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	0	0
TOTAL LIABILITIES	0	0
Level 1 \| Price risk management instruments \| Electric
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	0	0
TOTAL LIABILITIES	0	0
Level 1 \| Price risk management instruments \| Gas
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	0	0
TOTAL LIABILITIES	0	0
Level 1 \| Life insurance contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi trusts	0	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Short-term investments	0	0
Total nuclear decommissioning trusts	866	835
Rabbi trusts	180	185
Long-term disability trust	0	0
TOTAL ASSETS	1,059	1,023
Level 2 \| Short-term investments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Long-term disability trust	0	0
Level 2 \| Global equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 2 \| Fixed-income securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	866	835
Rabbi trusts	104	106
Level 2 \| Price risk management instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	13	3
TOTAL LIABILITIES	21	4
Level 2 \| Price risk management instruments \| Electric
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	9	2
TOTAL LIABILITIES	11	1
Level 2 \| Price risk management instruments \| Gas
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	4	1
TOTAL LIABILITIES	10	3
Level 2 \| Life insurance contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi trusts	76	79
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Short-term investments	0	0
Total nuclear decommissioning trusts	0	0
Rabbi trusts	0	0
Long-term disability trust	0	0
TOTAL ASSETS	214	166
Level 3 \| Short-term investments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Long-term disability trust	0	0
Level 3 \| Global equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Level 3 \| Fixed-income securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Rabbi trusts	0	0
Level 3 \| Price risk management instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	214	166
TOTAL LIABILITIES	248	238
Level 3 \| Price risk management instruments \| Electric
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	214	166
TOTAL LIABILITIES	248	238
Level 3 \| Price risk management instruments \| Gas
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total price risk management instruments	0	0
TOTAL LIABILITIES	0	0
Level 3 \| Life insurance contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi trusts	0	0
Assets measured at NAV
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	31	25
Long-term disability trust	$ 132	$ 158

FAIR VALUE MEASUREMENTS (Level

FAIR VALUE MEASUREMENTS (Level 3 Measurements and Sensitivity Analysis) (Details) $ in Millions	Dec. 31, 2021USD ($)$ / shares	Dec. 31, 2020USD ($)$ / shares
Market approach \| Congestion revenue rights
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets \| $	$ 188	$ 153
Liabilities \| $	93	74
Discounted cash flow \| Power purchase agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets \| $	26	13
Liabilities \| $	$ 155	$ 164
CRR auction prices \| Market approach \| Congestion revenue rights \| Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range (in dollars per mwh)	(40.77)	(320.25)
CRR auction prices \| Market approach \| Congestion revenue rights \| Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range (in dollars per mwh)	2,265.94	320.25
CRR auction prices \| Market approach \| Congestion revenue rights \| Weighted average price
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range (in dollars per mwh)	0.40	0.30
Forward prices \| Discounted cash flow \| Power purchase agreements \| Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range (in dollars per mwh)	(7.97)	12.56
Forward prices \| Discounted cash flow \| Power purchase agreements \| Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range (in dollars per mwh)	256.20	148.30
Forward prices \| Discounted cash flow \| Power purchase agreements \| Weighted average price
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range (in dollars per mwh)	47.17	35.52

FAIR VALUE MEASUREMENTS (Leve_2

FAIR VALUE MEASUREMENTS (Level 3 Reconciliation) (Details) - Level 3 - Price risk management instruments - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Asset (liability) balance, beginning of period	$ (72)	$ 5
Included in regulatory assets and liabilities or balancing accounts	38	(77)
Asset (liability) balance, end of period	$ (34)	$ (72)

FAIR VALUE MEASUREMENTS (Carryi

FAIR VALUE MEASUREMENTS (Carrying Amount and Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Carrying Amount
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	$ 4,619	$ 1,901
Carrying Amount \| Pacific Gas & Electric Co (Utility)
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	31,816	29,664
Level 2 \| Level 2 Fair Value
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	4,796	2,175
Level 2 \| Level 2 Fair Value \| Pacific Gas & Electric Co (Utility)
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	$ 35,803	$ 32,632

FAIR VALUE MEASUREMENTS (Schedu

FAIR VALUE MEASUREMENTS (Schedule of Unrealized Gains Losses Related to Available-for-sale Investments) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	$ 2,439	$ 2,180
Total Unrealized Gains	2,164	2,033
Total Unrealized Losses	(22)	(4)
Total Fair Value	4,581	4,209
Amount primarily related to deferred taxes on appreciation of investment value	783	671
Short-term investments
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	22	27
Total Unrealized Gains	0	0
Total Unrealized Losses	0	0
Total Fair Value	22	27
Global equity securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	479	543
Total Unrealized Gains	2,066	1,881
Total Unrealized Losses	(10)	(1)
Total Fair Value	2,535	2,423
Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	1,938	1,610
Total Unrealized Gains	98	152
Total Unrealized Losses	(12)	(3)
Total Fair Value	$ 2,024	$ 1,759

FAIR VALUE MEASUREMENTS (Sche_2

FAIR VALUE MEASUREMENTS (Schedule of Maturities on Debt Securities) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Debt Securities, Available-for-sale [Line Items]
Total maturities of fixed-income securities	$ 4,581	$ 4,209
Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Less than 1 year	97
1–5 years	495
5–10 years	480
More than 10 years	952
Total maturities of fixed-income securities	$ 2,024	$ 1,759

FAIR VALUE MEASUREMENTS (Sche_3

FAIR VALUE MEASUREMENTS (Schedule of Activity for Debt and Equity Securities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Proceeds from sales and maturities of nuclear decommissioning investments	$ 1,678	$ 1,518	$ 956
Gross realized gains on securities	286	159	69
Gross realized losses on securities	$ (19)	$ (41)	$ (14)

EMPLOYEE BENEFIT PLANS (Reconci

EMPLOYEE BENEFIT PLANS (Reconciliation of Changes in Plan Assets Benefit Obligations and Funded Status) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Funded Status:
Noncurrent liability	$ (860)	$ (2,444)
Pension Plan
Change in plan assets:
Fair value of plan assets at beginning of year	20,759	18,547
Actual return on plan assets	1,693	2,736
Company contributions	335	343
Benefits and expenses paid	(892)	(867)
Fair value of plan assets at end of year	21,895	20,759	$ 18,547
Change in benefit obligation:
Benefit obligation at beginning of year	23,172	20,525
Service cost for benefits earned	587	530	443
Interest cost	645	713	758
Actuarial (gain) loss	(752)	2,271
Plan amendments	0	0
Benefits and expenses paid	(893)	(867)
Benefit obligation at end of year	22,759	23,172	20,525
Funded Status:
Current liability	(9)	(3)
Noncurrent liability	(856)	(2,410)
Net (liability) asset at end of year	(865)	(2,413)
Accumulated benefit obligation	20,400	20,700
PBOP Plans
Change in plan assets:
Fair value of plan assets at beginning of year	2,995	2,678
Actual return on plan assets	193	379
Company contributions	10	26
Plan participant contribution	80	81
Benefits and expenses paid	(176)	(169)
Fair value of plan assets at end of year	3,102	2,995	2,678
Change in benefit obligation:
Benefit obligation at beginning of year	1,876	1,832
Service cost for benefits earned	63	61	56
Interest cost	51	63	76
Actuarial (gain) loss	(152)	(14)
Benefits and expenses paid	(156)	(149)
Federal subsidy on benefits paid	4	3
Plan participant contributions	80	80
Benefit obligation at end of year	1,766	1,876	$ 1,832
Funded Status:
Noncurrent asset	1,340	1,153
Noncurrent liability	(4)	(34)
Net (liability) asset at end of year	1,336	1,119
PBOP Plans \| Postretirement Life Insurance Plan
Change in plan assets:
Fair value of plan assets at beginning of year	343
Fair value of plan assets at end of year	359	343
Change in benefit obligation:
Benefit obligation at beginning of year	377
Benefit obligation at end of year	$ 363	$ 377

EMPLOYEE BENEFIT PLANS (Compone

EMPLOYEE BENEFIT PLANS (Components of Net Periodic Benefit Cost) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	$ 587	$ 530	$ 443
Interest cost	645	713	758
Expected return on plan assets	(1,046)	(1,044)	(906)
Amortization of prior service cost	(6)	(6)	(6)
Amortization of net actuarial loss	6	3	3
Net periodic benefit cost	186	196	292
Less: transfer to regulatory account	147	136	42
Total expense recognized	333	332	334
PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	63	61	56
Interest cost	51	63	76
Expected return on plan assets	(137)	(138)	(123)
Amortization of prior service cost	14	14	14
Amortization of net actuarial loss	(33)	(21)	(3)
Net periodic benefit cost	$ (42)	$ (21)	$ 20

EMPLOYEE BENEFIT PLANS (Schedul

EMPLOYEE BENEFIT PLANS (Schedule of Assumptions Used in Calculating Projected Benefit Cost and Net Periodic Benefit Cost) (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	9.60%
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Discount rate	3.03%	2.77%	3.46%
Rate of future compensation increases	3.80%	3.80%	3.90%
Expected return on plan assets	5.50%	5.10%	5.70%
Interest crediting rate for cash balance plan	1.95%	1.95%	2.11%
PBOP Plans \| Minimum
Defined Benefit Plan Disclosure [Line Items]
Discount rate	2.97%	2.67%	3.37%
Expected return on plan assets	3.30%	3.10%	3.50%
PBOP Plans \| Maximum
Defined Benefit Plan Disclosure [Line Items]
Discount rate	3.04%	2.80%	3.47%
Expected return on plan assets	6.40%	6.10%	6.60%

EMPLOYEE BENEFIT PLANS (Narrati

EMPLOYEE BENEFIT PLANS (Narrative) (Details) $ in Millions	12 Months Ended
EMPLOYEE BENEFIT PLANS (Narrative) (Details) $ in Millions	Dec. 31, 2021USD ($)noncallable_bond	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Defined Benefit Plan Disclosure [Line Items]
Assumed health care cost trend rate	6.00%
Ultimate trend rate	4.50%
Assumed return	5.50%
10 year actual rate of return	9.60%
Number of Aa-grade non-callable bonds used to develop the yield curve for rate used (noncallable bond) \| noncallable_bond	817
Total fair value of trust other net liabilities	$ (175)	$ 249
Retirement savings plan expense	$ 133	$ 119	$ 109
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
10 year actual rate of return	5.50%	5.10%	5.70%
Company contributions	$ 335	$ 343
Expected employer contribution next year	327
PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
Company contributions	10	$ 26
Expected employer contribution next year	$ 15

EMPLOYEE BENEFIT PLANS (Target

EMPLOYEE BENEFIT PLANS (Target Asset Allocation Percentages) (Details)	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		100.00%	100.00%
Pension Plan \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		30.00%	30.00%
Pension Plan \| Absolute return
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		2.00%	2.00%
Pension Plan \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		8.00%	8.00%
Pension Plan \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		60.00%	60.00%
PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		100.00%	100.00%
PBOP Plans \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		36.00%	28.00%
PBOP Plans \| Absolute return
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		1.00%	2.00%
PBOP Plans \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		5.00%	8.00%
PBOP Plans \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		58.00%	62.00%
Forecast \| Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	100.00%
Forecast \| Pension Plan \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	30.00%
Forecast \| Pension Plan \| Absolute return
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	2.00%
Forecast \| Pension Plan \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	8.00%
Forecast \| Pension Plan \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	60.00%
Forecast \| PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	100.00%
Forecast \| PBOP Plans \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	26.00%
Forecast \| PBOP Plans \| Absolute return
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	1.00%
Forecast \| PBOP Plans \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	3.00%
Forecast \| PBOP Plans \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	70.00%

EMPLOYEE BENEFIT PLANS (Sched_2

EMPLOYEE BENEFIT PLANS (Schedule of Fair Value of Plan Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	$ 25,172	$ 24,003
Level 3
Defined Benefit Plan Disclosure [Line Items]
Assets measured at NAV	27	12	$ 15
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	22,054	20,993
Assets measured at NAV	21,895	20,759	18,547
Pension Plan \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	807	742
Pension Plan \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	2,498	1,875
Pension Plan \| Absolute Return
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1	2
Pension Plan \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	632	517
Pension Plan \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	10,144	9,633
Pension Plan \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	5,987	5,194
Pension Plan \| Level 1 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	552	334
Pension Plan \| Level 1 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	2,074	1,875
Pension Plan \| Level 1 \| Absolute Return
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	1
Pension Plan \| Level 1 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	632	517
Pension Plan \| Level 1 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	2,729	2,467
Pension Plan \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	8,068	7,563
Pension Plan \| Level 2 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	255	408
Pension Plan \| Level 2 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	424	0
Pension Plan \| Level 2 \| Absolute Return
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1	1
Pension Plan \| Level 2 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
Pension Plan \| Level 2 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	7,388	7,154
Pension Plan \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	27	12
Pension Plan \| Level 3 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
Pension Plan \| Level 3 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
Pension Plan \| Level 3 \| Absolute Return
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
Pension Plan \| Level 3 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
Pension Plan \| Level 3 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	27	12
Pension Plan \| Assets measured at NAV
Defined Benefit Plan Disclosure [Line Items]
Assets measured at NAV	7,972	8,224
PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	3,118	3,010
Assets measured at NAV	3,102	2,995	$ 2,678
PBOP Plans \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	31	37
PBOP Plans \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	105	173
PBOP Plans \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	34	54
PBOP Plans \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1,652	1,197
PBOP Plans \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	946	745
PBOP Plans \| Level 1 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	31	37
PBOP Plans \| Level 1 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	105	173
PBOP Plans \| Level 1 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	34	54
PBOP Plans \| Level 1 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	776	481
PBOP Plans \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	875	715
PBOP Plans \| Level 2 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 2 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 2 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 2 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	875	715
PBOP Plans \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1	1
PBOP Plans \| Level 3 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 3 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 3 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 3 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1	1
PBOP Plans \| Assets measured at NAV
Defined Benefit Plan Disclosure [Line Items]
Assets measured at NAV	$ 1,296	$ 1,549

EMPLOYEE BENEFIT PLANS (Sched_3

EMPLOYEE BENEFIT PLANS (Schedule of Level 3 Reconciliation) (Details) - Level 3 - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan, Change in Fair Value of Plan Assets, Level 3 Reconciliation [Roll Forward]
Fair value of plan assets at beginning of year	$ 12	$ 15
Actual return on plan assets:
Relating to assets still held at the reporting date	6	2
Relating to assets sold during the period	(7)	(3)
Purchases, issuances, sales, and settlements:
Purchases	22	11
Settlements	(6)	(13)
Fair value of plan assets at end of year	$ 27	$ 12

EMPLOYEE BENEFIT PLANS (Sched_4

EMPLOYEE BENEFIT PLANS (Schedule of Estimated Benefits Expected to Be Paid) (Details) $ in Millions	Dec. 31, 2021USD ($)
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
2022	$ 869
2023	954
2024	988
2025	1,018
2026	1,046
Thereafter in the succeeding five years	5,533
PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
2022	81
2023	85
2024	89
2025	88
2026	91
Thereafter in the succeeding five years	466
Federal Subsidy
Defined Benefit Plan Disclosure [Line Items]
2022	(3)
2023	(3)
2024	(3)
2025	(3)
2026	(3)
Thereafter in the succeeding five years	$ (3)

RELATED PARTY AGREEMENTS AND _3

RELATED PARTY AGREEMENTS AND TRANSACTIONS (Summary of Significant Related Party Transactions) (Details) - Pacific Gas & Electric Co (Utility) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Administrative services provided to PG&E Corporation
Related Party Transaction [Line Items]
Utility revenues from	$ 3	$ 3	$ 4
Administrative services received from PG&E Corporation
Related Party Transaction [Line Items]
Utility expenses from	82	108	107
Utility employee benefit due to PG&E Corporation
Related Party Transaction [Line Items]
Utility expenses from	$ 39	$ 34	$ 42

RELATED PARTY AGREEMENTS AND _4

RELATED PARTY AGREEMENTS AND TRANSACTIONS (Narrative) (Details) - USD ($) $ in Millions	Aug. 11, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Intercompany note to PG&E Corporation	$ 145
Intercompany Loan
Related Party Transaction [Line Items]
Debt Instrument, term	364 days
Pacific Gas & Electric Co (Utility)
Related Party Transaction [Line Items]
Current receivables		$ 173	$ 35
Current payables		19	46
Intercompany note to PG&E Corporation		$ 145	$ 0	$ 0

WILDFIRE-RELATED CONTINGENCIE_2

WILDFIRE-RELATED CONTINGENCIES (2019 Kincade Fire, 2020 Zogg Fire and 2021 Dixie Fire) (Details) numberOfPeople in Millions, $ in Millions	Oct. 29, 2021USD ($)a	Oct. 18, 2021USD ($)	Nov. 04, 2019numberOfPeople	Dec. 31, 2021USD ($)	Sep. 30, 2021USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Feb. 03, 2022complaintnumberOfClaimHolderplaintiffnumberOfPlaintiff	Jan. 28, 2022countnotice	Jan. 27, 2022notice	Dec. 02, 2021transmissionLine	Nov. 18, 2021notice	Sep. 24, 2021felonymisdemeanor	Jul. 13, 2021afatalitystructure	May 11, 2021count	Apr. 06, 2021felonymisdemeanor	Sep. 27, 2020ainjuryfatalitystructure	Dec. 31, 2019USD ($)	Oct. 23, 2019ainjurynumberOfFatalitystructure
Loss Contingencies [Line Items]
Insurance receivable				$ 1,247		$ 1,247	$ 674											$ 2,238
2019 Kincade fire
Loss Contingencies [Line Items]
Number of acres burned (acre) \| a																			77,758
Number of fatalities (fatality) \| numberOfFatality																			0
Number of injuries \| injury																			4
Number of structures destroyed (structure) \| structure																			374
Number of structures damaged (structure) \| structure																			60
Number of people part of mandatory evacuation order \| numberOfPeople			0.2
Number of transmission lines \| transmissionLine											70
Loss contingency liability				769		769	625											0
Fire fighting costs recovery requested		$ 90
Potential loss contingency, additional						175
Potential loss contingency						800
Insurance receivable				414		414	430											0
Insurance receivable				430		430
2019 Kincade fire \| Subsequent Event
Loss Contingencies [Line Items]
Number of felonies (felony) \| notice									5	2
Number of demurrer filed (count) \| count									22
Number of criminal complaints (count) \| count									30
Number of misdemeanors dropped (misdemeanor) \| notice									6
Number of complaints (complaint) \| complaint								100
Number of plaintiffs represented by complaints \| plaintiff								2,605
2019 Kincade fire \| Pacific Gas & Electric Co (Utility)
Loss Contingencies [Line Items]
Number of demurrer filed (count) \| count															25
Number of criminal complaints (count) \| count															33
Loss contingency liability				40		40
May not seek recovery to remove permanently abandoned transmission lines						85
2019 Kincade fire \| Pacific Gas & Electric Co (Utility) \| Sonoma Contry District Attorney
Loss Contingencies [Line Items]
Number of felonies (felony) \| felony																5
Number of misdemeanors (misdemeanor) \| misdemeanor																28
2020 Zogg fire
Loss Contingencies [Line Items]
Number of acres burned (acre) \| a																	56,338
Number of fatalities (fatality) \| fatality																	4
Number of injuries \| injury																	1
Number of structures destroyed (structure) \| structure																	204
Number of structures damaged (structure) \| structure																	27
Number of demurrer filed (count) \| notice												10
Number of criminal complaints (count) \| notice												31
Loss contingency liability				211		211	275											0
Potential loss contingency, additional					$ 100
Potential loss contingency						375	275
Insurance receivable				270		270	219											0
Liability insurance coverage				611		611
Initial self-insured retention per occurrence				60		60
Legal fees						22
Insurance receivable				337		337
2020 Zogg fire \| Subsequent Event
Loss Contingencies [Line Items]
Number of complaints (complaint) \| complaint								21
Number of plaintiffs represented by complaints \| numberOfPlaintiff								382
2020 Zogg fire \| Maximum
Loss Contingencies [Line Items]
Liability insurance coverage							867.5
Zogg Complaint, 2020
Loss Contingencies [Line Items]
Number of felonies (felony) \| felony													11
Number of misdemeanors (misdemeanor) \| misdemeanor													20
2021 Dixie fire
Loss Contingencies [Line Items]
Number of acres burned (acre) \| a														963,309
Number of fatalities (fatality) \| fatality														1
Number of structures destroyed (structure) \| structure														1,329
Number of structures damaged (structure) \| structure														95
May not seek recovery to remove permanently abandoned transmission lines	$ 630
Potential loss contingency				1,150
Insurance receivable				563		563	$ 0											$ 0
Number of residential structures destroyed (structure) \| structure														717
Number of commercial structures destroyed (structure) \| structure														143
Number of other structures destroyed (structure) \| structure														443
Insurance receivable				563		563
Probable of recovery						1,161
2021 Dixie fire \| Subsequent Event
Loss Contingencies [Line Items]
Number of complaints (complaint) \| numberOfClaimHolder								20
Number of plaintiffs represented by complaints \| numberOfClaimHolder								1,005
2021 Dixie fire \| FERC TO rates
Loss Contingencies [Line Items]
Probable of recovery						101
2021 Dixie fire \| WEMA
Loss Contingencies [Line Items]
Probable of recovery						347
2021 Dixie fire \| National Park
Loss Contingencies [Line Items]
Number of acres burned (acre) \| a	70,000
2021 Dixie fire \| National Forrest
Loss Contingencies [Line Items]
Number of acres burned (acre) \| a	685,000
Zogg Fire, 2020 and Dixie Fire, 2021
Loss Contingencies [Line Items]
Liability insurance coverage				$ 900		$ 900

WILDFIRE-RELATED CONTINGENCIE_3

WILDFIRE-RELATED CONTINGENCIES (Loss Recoveries) (Details) - 2021 Dixie fire $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Loss Contingencies [Line Items]
Probable of recovery	$ 1,161
Insurance
Loss Contingencies [Line Items]
Probable of recovery	563
FERC TO rates
Loss Contingencies [Line Items]
Probable of recovery	101
WEMA
Loss Contingencies [Line Items]
Probable of recovery	347
Wildfire Fund
Loss Contingencies [Line Items]
Probable of recovery	$ 150

WILDFIRE-RELATED CONTINGENCIE_4

WILDFIRE-RELATED CONTINGENCIES (Losses For Claims) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
2019 Kincade fire
Loss Contingency Accrual [Roll Forward]
Loss accrual, beginning balance	$ 625	$ 0
Accrued Losses	175	625
Payments	(31)	0
Loss accrual, ending balance	769	625
2019 Kincade fire \| Pacific Gas & Electric Co (Utility)
Loss Contingency Accrual [Roll Forward]
Loss accrual, ending balance	40
2020 Zogg fire
Loss Contingency Accrual [Roll Forward]
Loss accrual, beginning balance	275	0
Accrued Losses	100	275
Payments	(164)	0
Loss accrual, ending balance	$ 211	$ 275

WILDFIRE-RELATED CONTINGENCIE_5

WILDFIRE-RELATED CONTINGENCIES (Insurance) (Details) - USD ($) $ in Millions	Apr. 29, 2021	Jun. 30, 2021	Dec. 31, 2021	Aug. 31, 2020
Loss Contingencies [Line Items]
Prepaid insurance			$ 358
Insurance premium costs, recovery, coverage amount			1,400
Insurance Coverage for Wildfire Events
Loss Contingencies [Line Items]
Initial self-insured retention per occurrence			60
Insurance Coverage for Wildfire Events \| August 1, 2019 through July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage	$ 268
Reinsurance	32
Costs for insurance coverage	$ 220
Insurance Coverage for Wildfire Events \| September 3, 2019 through September 2, 2020
Loss Contingencies [Line Items]
Reinsurance				$ 11
Insurance Coverage for Wildfire Events \| August 1, 2019 through July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage				$ 600
Insurance Coverage for Wildfire Events \| August 1, 2019 through September 2, 2020
Loss Contingencies [Line Items]
Costs for insurance coverage			$ 516
Insurance Coverage for Wildfire Events \| July 1, 2020 - June 30, 2021
Loss Contingencies [Line Items]
Costs for insurance coverage		$ 89
Insurance Coverage For Non-Wildfire Liabilities
Loss Contingencies [Line Items]
Initial self-insured retention per occurrence		10
Insurance Coverage For Non-Wildfire Liabilities \| August 1, 2019 through July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage		50
Insurance Coverage For Non-Wildfire Liabilities \| August 1, 2019 through July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage		140
Insurance Coverage For Non-Wildfire Liabilities \| July 1, 2020 - June 30, 2021
Loss Contingencies [Line Items]
Liability insurance coverage		535
Insurance Coverage For Non-Wildfire Liabilities \| August 1, 2020 - July 31, 2021
Loss Contingencies [Line Items]
Costs for insurance coverage		$ 30

WILDFIRE-RELATED CONTINGENCIE_6

WILDFIRE-RELATED CONTINGENCIES (Insurance Receivable) (Details) - USD ($) $ in Millions	Jan. 26, 2022	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance			$ 674	$ 2,238
Accrued insurance recoveries			681	649
Reimbursements			(108)	(2,213)
Insurance Receivable, Ending Balance		$ 1,247	1,247	674
2021 Dixie fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance			0	0
Accrued insurance recoveries			563	0
Reimbursements			0	0
Insurance Receivable, Ending Balance		563	563	0
Insurance receivable		563	563
Accrued insurance recoveries, increase (decrease)		(6.5)
2020 Zogg fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance			219	0
Accrued insurance recoveries			118	219
Reimbursements			(67)	0
Insurance Receivable, Ending Balance		270	270	219
Insurance receivable		337	337
Accrued insurance recoveries, increase (decrease)		6.5
2020 Zogg fire \| Subsequent Event
Insurance Receivable [Roll Forward]
Reimbursements	$ (43)
2019 Kincade fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance			430	0
Accrued insurance recoveries			0	430
Reimbursements			(16)	0
Insurance Receivable, Ending Balance		414	414	430
Insurance receivable		430	430
2018 Camp fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance			0	1,380
Accrued insurance recoveries			0	0
Reimbursements			0	(1,380)
Insurance Receivable, Ending Balance		0	0	0
2017 Northern California wildfires
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance			25	808
Accrued insurance recoveries			0	0
Reimbursements			(25)	(783)
Insurance Receivable, Ending Balance		0	0	25
2015 Butte fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance			0	50
Accrued insurance recoveries			0	0
Reimbursements			0	(50)
Insurance Receivable, Ending Balance		$ 0	$ 0	$ 0

WILDFIRE-RELATED CONTINGENCIE_7

WILDFIRE-RELATED CONTINGENCIES (Regulatory Recovery) (Details) - 2021 Dixie fire $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Loss Contingencies [Line Items]
Probable of recovery	$ 1,161
FERC TO rates
Loss Contingencies [Line Items]
Probable of recovery	101
WEMA
Loss Contingencies [Line Items]
Probable of recovery	$ 347

WILDFIRE-RELATED CONTINGENCIE_8

WILDFIRE-RELATED CONTINGENCIES (Wildfire Fund) (Details) - USD ($) $ in Millions	Aug. 23, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jul. 12, 2019
Loss Contingencies [Line Items]
Disallowance cap, transmission and distribution equity rate base					$ 2,900
Initial safety certification, documentation provided, period	90 days
Initial safety certification, period	12 months
Expected capitalization, proceeds of bond		$ 10,500
Expected capitalization, initial contribution		7,500
Expected capitalization, annual contribution		300
Insurance receivable		1,247	$ 674	$ 2,238
2021 Dixie fire
Loss Contingencies [Line Items]
Insurance receivable		$ 563	$ 0	$ 0

WILDFIRE-RELATED CONTINGENCIE_9

WILDFIRE-RELATED CONTINGENCIES (Wildfire-Related Derivative Litigation) (Details) - Breach of Fiduciary Duties	Feb. 24, 2021notice	Nov. 20, 2017lawsuit	Nov. 16, 2017lawsuit
Loss Contingencies [Line Items]
Number of causes of action (causes) \| notice	2
Derivative Lawsuits Filed in the San Francisco County Superior Court
Loss Contingencies [Line Items]
Number of lawsuits filed against company (lawsuit, complaint) \| lawsuit		2	2

WILDFIRE-RELATED CONTINGENCI_10

WILDFIRE-RELATED CONTINGENCIES (Wildfire-Related Securities Class Action Litigation and Debt Claims) (Details)	Dec. 31, 2021lawsuit	Feb. 22, 2019offering	Jun. 30, 2018lawsuit
Wildfire-Related Class Action
Loss Contingencies [Line Items]
Number of lawsuits filed against company (lawsuit, complaint)			2
Number of public offerings of notes with complaints against underwriters (offering) \| offering		4
Satisfaction of HoldCo Rescission or Damage Claims and Subordinated Debt
Loss Contingencies [Line Items]
Number of lawsuits filed against company (lawsuit, complaint)	3

WILDFIRE-RELATED CONTINGENCI_11

WILDFIRE-RELATED CONTINGENCIES (De-energization Class Action) (Details) $ in Millions	Nov. 02, 2021USD ($)
De-energization Class Action
Loss Contingencies [Line Items]
Litigation settlement, amount awarded from other party	$ 10

WILDFIRE-RELATED CONTINGENCI_12

WILDFIRE-RELATED CONTINGENCIES (District Attorneys Offices Investigations) (Details) - Pacific Gas & Electric Co (Utility) - Complaints Brought By Butte County District Attorney - Loss from Wildfires	Mar. 17, 2020count
Loss Contingencies [Line Items]
Number of guilty involuntary manslaughter pleas	84
Number of count related to unlawfully causing a fire (count)	1

WILDFIRE- RELATED CONTINGENCIES

WILDFIRE- RELATED CONTINGENCIES (Restructuring Support Agreement) (Details) - USD ($) $ in Millions	Jan. 18, 2022	Jan. 15, 2021	Jul. 01, 2020	Jun. 12, 2020
Loss Contingencies [Line Items]
Payment of plan of reorganization, tax benefits payment agreement		$ 758
Fire Victim Trust
Loss Contingencies [Line Items]
Cash contribution by company			$ 5,400
Percentage of common stock owned, Fire Victim Trust if common issues additional shares				22.19%
Pacific Gas & Electric Co (Utility)
Loss Contingencies [Line Items]
Plan of reorganization, future tax benefits payment agreement			$ 1,350
Pacific Gas & Electric Co (Utility) \| On Or Before January 15, 2022 \| Subsequent Event
Loss Contingencies [Line Items]
Cash	$ 592

OTHER CONTINGENCIES AND COMMI_3

OTHER CONTINGENCIES AND COMMITMENTS (Order Instituting Investigation Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Apr. 20, 2020	Dec. 17, 2019
Loss Contingencies [Line Items]
Expenses and capital expenditures, disallowed costs	$ 1,625
Expenses and capital expenditures, disallowed capital, approved		$ 198
Shareholder-funded system enhancement initiatives, approved		64
Fine payable to general fund, suspended		$ 200
Wildfire mitigation plan memorandum account
Loss Contingencies [Line Items]
Expenses and capital expenditures, disallowed capital, approved	198
Pacific Gas & Electric Co (Utility)
Loss Contingencies [Line Items]
Expenses and capital expenditures	1,625
Pacific Gas & Electric Co (Utility) \| Pending Litigation \| Unfavorable Regulatory Action
Loss Contingencies [Line Items]
Expenses and capital expenditures	$ 1,625
Shareholder-funded system enhancement initiatives, amount			$ 50

OTHER CONTINGENCIES AND COMMI_4

OTHER CONTINGENCIES AND COMMITMENTS (Order Instituting Investigation Legal Obligation) (Details) - Pacific Gas & Electric Co (Utility) $ in Millions	Dec. 31, 2021USD ($)
Loss Contingencies [Line Items]
Expense	$ 1,222
Capital	403
Total	1,625
Distribution Safety Inspections and Repairs Expense (FRMMA/WMPMA)
Loss Contingencies [Line Items]
Expense	236
Capital	0
Total	236
Transmission Safety Inspections and Repairs Expense (TO)
Loss Contingencies [Line Items]
Expense	433
Capital	0
Total	433
Vegetation Management Support Costs (FHPMA)
Loss Contingencies [Line Items]
Expense	36
Capital	0
Total	36
2017 Northern California Wildfires CEMA Expense and Capital (CEMA)
Loss Contingencies [Line Items]
Expense	82
Capital	66
Total	148
2018 Camp Fire CEMA Expense (CEMA)
Loss Contingencies [Line Items]
Expense	435
Capital	0
Total	435
2018 Camp Fire CEMA Capital for Restoration (CEMA)
Loss Contingencies [Line Items]
Expense	0
Capital	253
Total	253
2018 Camp Fire CEMA Capital for Temporary Facilities (CEMA)
Loss Contingencies [Line Items]
Expense	0
Capital	84
Total	$ 84

OTHER CONTINGENCIES AND COMMI_5

OTHER CONTINGENCIES AND COMMITMENTS (Transmission Owner Rate) (Details) - USD ($) $ in Millions	Sep. 21, 2018	Dec. 31, 2021
Transmission Owner Rate Case Revenue
Loss Contingencies [Line Items]
Regulatory liabilities		$ 324
Regulatory assets		$ 197
Pacific Gas & Electric Co (Utility) \| Electric
Loss Contingencies [Line Items]
Requested revenue rate	98.85%

OTHER CONTINGENCIES AND COMMI_6

OTHER CONTINGENCIES AND COMMITMENTS (Interim Rate Relief Subject to Refund) (Details) $ in Millions	Sep. 21, 2021USD ($)	Dec. 31, 2021USD ($)	Nov. 02, 2021USD ($)	Oct. 23, 2020USD ($)	Sep. 30, 2020USD ($)	Aug. 07, 2019USD ($)	Apr. 25, 2019USD ($)	Mar. 30, 2018USD ($)catastrophicEvent
Loss Contingencies [Line Items]
Expenses and capital expenditures, disallowed costs		$ 1,625
CEMA Interim Rate Relief
Loss Contingencies [Line Items]
Cost recovery		373	$ 683			$ 763	$ 373
CEMA Interim Rate Relief \| Mid 2016 - Early 2017
Loss Contingencies [Line Items]
Cost recovery								$ 183
Number of catastrophic events \| catastrophicEvent								7
CEMA Interim Rate Relief \| 2016 to 2017
Loss Contingencies [Line Items]
Cost recovery								$ 405
WMCE Interim Rate Relief
Loss Contingencies [Line Items]
Expenses and capital expenditures, disallowed costs					$ 1,180
Expenses and capital expenditures, capital expenditures					801
Cost recovery, increase to revenue requirement					$ 1,280
Capital expenditures for future recovery				$ 447
Interim revenue requirement	$ 447
Amortization period	17 months
Additional revenue requirement	$ 591
Additional amortization period	24 months
WMCE Interim Rate Relief \| Fire hazard prevention memorandum account
Loss Contingencies [Line Items]
Cost recovery		293
WMCE Interim Rate Relief \| Fire risk and wildfire mitigation memorandum account
Loss Contingencies [Line Items]
Cost recovery		740
WMCE Interim Rate Relief \| Catastrophic event memorandum account
Loss Contingencies [Line Items]
Cost recovery		$ 251

OTHER CONTINGENCIES AND COMMI_7

OTHER CONTINGENCIES AND COMMITMENTS (2015 Gas Transmission and Storage Rate Case and 2011-2014 Gas Transmission and Storage Capital Expenditures Audit) (Details) - Disallowance of Plant Costs - USD ($) $ in Millions	Jul. 07, 2021	Jun. 23, 2016	Jul. 31, 2020
Loss Contingencies [Line Items]
Gas transmission and storage capital disallowance		$ 696
Permanently disallowed capital		120
Amount subject to audit		$ 576
Capital expenditures for future recovery			$ 512
Loss Contingency Nature, Period One
Loss Contingencies [Line Items]
Capital expenditures for future recovery, seeking recovery			$ 416.3
Capital expenditures for future recovery, pending authorization	$ 356.3
Loss Contingency Nature, Period Two
Loss Contingencies [Line Items]
Capital expenditures for future recovery, pending authorization	$ 313.3
Capital expenditures for future recovery, pending authorization, amortization period	60 months
Loss Contingency Nature, Period Three
Loss Contingencies [Line Items]
Capital expenditures for future recovery, pending authorization	$ 43
Capital expenditures for future recovery, pending authorization, amortization period	12 months

OTHER CONTINGENCIES AND COMMI_8

OTHER CONTINGENCIES AND COMMITMENTS (Other Matters) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Accrued legal liabilities	$ 77	$ 144

OTHER CONTINGENCIES AND COMMI_9

OTHER CONTINGENCIES AND COMMITMENTS (PSPS Class Action) (Details) $ in Billions	Dec. 19, 2019USD ($)
PSPS Class Action \| Pending Litigation \| Pacific Gas & Electric Co (Utility)
Loss Contingencies [Line Items]
Loss contingency, damages sought	$ 2.5

OTHER CONTINGENCIES AND COMM_10

OTHER CONTINGENCIES AND COMMITMENTS (Schedule Environmental Remediation Liability Composed) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Disclosure Commitments And Contingencies Environmental Remediation Liability Composed [Abstract]
Topock natural gas compressor station	$ 299	$ 303
Hinkley natural gas compressor station	123	132
Former manufactured gas plant sites owned by the Utility or third parties	667	659
Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites	104	111
Fossil fuel-fired generation facilities and sites	70	96
Total environmental remediation liability	$ 1,263	$ 1,301

OTHER CONTINGENCIES AND COMM_11

OTHER CONTINGENCIES AND COMMITMENTS (Environmental Remediation Contingencies Narrative) (Details) $ in Millions	Dec. 31, 2021USD ($)
Long-term Purchase Commitment [Line Items]
Amount of environmental loss accrual expected to be recovered	$ 982
Topock Site
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 220
Topock Site \| Pacific Gas & Electric Co (Utility)
Long-term Purchase Commitment [Line Items]
Remediation cost recovery percentage	90.00%
Hinkley Natural Gas Compressor Station
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 138
Former Manufactured Gas Plant
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 477
Former Manufactured Gas Plant \| Pacific Gas & Electric Co (Utility)
Long-term Purchase Commitment [Line Items]
Remediation cost recovery percentage	90.00%
Utility Owned Generation Facilities and Third Party Disposal Sites
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 50
Utility Owned Generation Facilities and Third Party Disposal Sites \| Pacific Gas & Electric Co (Utility)
Long-term Purchase Commitment [Line Items]
Remediation cost recovery percentage	90.00%
Fossil Fuel Fired Generation
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 43

OTHER CONTINGENCIES AND COMM_12

OTHER CONTINGENCIES AND COMMITMENTS (Nuclear Insurance) (Details)	12 Months Ended
	Dec. 31, 2021USD ($)nuclear_generating_unit
Long-term Purchase Commitment [Line Items]
Number of nuclear generating units (nuclear generating unit) \| nuclear_generating_unit	2
Maximum total payment incurred per event under the loss sharing program	$ 450,000,000
Nuclear Electric Insurance Limited and European Mutual Association for Nuclear Insurance
Long-term Purchase Commitment [Line Items]
Insurance coverage, loss	400,000,000
Humboldt Bay Unit
Long-term Purchase Commitment [Line Items]
Amount of property damage coverage provided by NEIL	50,000,000
Amount of liability insurance for Humboldt Bay Unit 3	53,000,000
Diablo Canyon
Long-term Purchase Commitment [Line Items]
Maximum public liability per nuclear incident under Price-Anderson Act	13,600,000,000
Maximum available public liability insurance for Diablo Canyon as required by Price-Anderson Act	450,000,000
Maximum annual payment incurred per event under the loss sharing program	275,000,000
Coverage for purchased public liability insurance, per incident	$ 41,000,000
Period for inflation adjustment	5 years
Nuclear Incident
Long-term Purchase Commitment [Line Items]
Amount of property damage and business interruption coverage provided by NEIL for Diablo Canyon	$ 3,200,000,000
Nuclear Incident \| Humboldt Bay Unit
Long-term Purchase Commitment [Line Items]
Amount of indemnification from the nuclear regulatory commission for public liability arising from nuclear incidents	500,000,000
Non-Nuclear Incident
Long-term Purchase Commitment [Line Items]
Amount of property damage and business interruption coverage provided by NEIL for Diablo Canyon	2,700,000,000
European Mutual Association for Nuclear Insurance
Long-term Purchase Commitment [Line Items]
Full insurance policy limit	200,000,000
Potential premium obligation	4,000,000
Nuclear Electric Insurance Limited
Long-term Purchase Commitment [Line Items]
Potential premium obligation	$ 42,000,000

OTHER CONTINGENCIES AND COMM_13

OTHER CONTINGENCIES AND COMMITMENTS (Schedule of Purchase Commitments) (Details) $ in Millions	Dec. 31, 2021USD ($)
Long-term Purchase Commitment [Line Items]
2022	$ 3,518
2023	2,761
2024	2,547
2025	2,443
2026	2,313
Thereafter	19,920
Total purchase commitments	33,502
Renewable Energy
Long-term Purchase Commitment [Line Items]
2022	2,062
2023	2,043
2024	2,020
2025	2,009
2026	1,948
Thereafter	19,310
Total purchase commitments	29,392
Conventional Energy
Long-term Purchase Commitment [Line Items]
2022	530
2023	425
2024	282
2025	216
2026	204
Thereafter	539
Total purchase commitments	2,196
Other
Long-term Purchase Commitment [Line Items]
2022	61
2023	61
2024	61
2025	61
2026	21
Thereafter	19
Total purchase commitments	284
Natural Gas
Long-term Purchase Commitment [Line Items]
2022	823
2023	191
2024	157
2025	157
2026	140
Thereafter	52
Total purchase commitments	1,520
Nuclear Fuel
Long-term Purchase Commitment [Line Items]
2022	42
2023	41
2024	27
2025	0
2026	0
Thereafter	0
Total purchase commitments	$ 110

OTHER CONTINGENCIES AND COMM_14

OTHER CONTINGENCIES AND COMMITMENTS (Third-Party Power Purchase Agreements and Other Agreements) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Power Purchases and Electric Capacity
Third-Party Power Purchase Agreements [Line Items]
Costs incurred for power purchases and electric capacity	$ 3,000	$ 2,900	$ 3,000
Nuclear Fuel
Third-Party Power Purchase Agreements [Line Items]
Payments for nuclear fuel	79	111	74
Gas Contracts
Third-Party Power Purchase Agreements [Line Items]
Cost of goods	$ 1,200	$ 800	$ 900

OTHER CONTINGENCIES AND COMM_15

OTHER CONTINGENCIES AND COMMITMENTS (Schedule of Other Commitments) (Details) $ in Millions	Dec. 31, 2021USD ($)
Commitments and Contingencies Disclosure [Abstract]
2022	$ 43
2023	65
2024	81
2025	77
2026	74
Thereafter	2,938
Total minimum lease payments	$ 3,278

OTHER CONTINGENCIES AND COMM_16

OTHER CONTINGENCIES AND COMMITMENTS (Other Commitments) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Leased Assets [Line Items]
Payments for other commitments	$ 50	$ 45	$ 48
Minimum
Operating Leased Assets [Line Items]
Extension option for operating leases	1 year
Maximum
Operating Leased Assets [Line Items]
Extension option for operating leases	5 years

OTHER CONTINGENCIES AND COMM_17

OTHER CONTINGENCIES AND COMMITMENTS (Oakland Headquarters Lease) (Details) ft² in Thousands, $ in Millions	Oct. 23, 2020USD ($)	Jun. 05, 2020USD ($)ft²
Commitments and Contingencies Disclosure [Abstract]
Rentable square feet \| ft²		910
Lease, option payment letter of credit	$ 75
Lease, security letter of credit	$ 75
Term of contract		34 years 11 months
Purchase options, land, value		$ 892

SCHEDULE I _ CONDENSED FINANC_2

SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT (Schedule of Condensed Income Statement and Comprehensive Income) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating expenses	$ (18,759)	$ (16,714)	$ (27,223)
Interest income	20	39	82
Interest expense	(1,601)	(1,260)	(934)
Other income, net	457	483	250
Reorganization items, net	(11)	(1,959)	(346)
Income tax provision (benefit)	836	362	(3,400)
Loss Attributable to Common Shareholders	(102)	(1,318)	(7,656)
Other Comprehensive Income (Loss)
Pension and other postretirement benefit plans obligations	7	(17)	(1)
Total other comprehensive income (loss)	$ 7	$ (17)	$ (1)
Weighted Average Common Shares Outstanding, Basic (in shares)	1,985,000,000	1,257,000,000	528,000,000
Weighted Average Common Shares Outstanding, Diluted (in shares)	1,985,000,000	1,257,000,000	528,000,000
Net Loss Per Common Share, Basic (in dollars per share)	$ (0.05)	$ (1.05)	$ (14.50)
Net Loss Per Common Share, Diluted (in dollars per share)	$ (0.05)	$ (1.05)	$ (14.50)
Pension and other postretirement benefit plans obligations, tax	$ 3	$ 7	$ 0
Treasury stock, shares at cost (in shares)	477,743,590	0
PG&E Corporation
Operating expenses	$ (124)	$ (103)	(114)
Interest income	0	0	1
Interest expense	(230)	(149)	(21)
Other income, net	(54)	13	10
Reorganization items, net	1	(1,649)	(26)
Equity in earnings of subsidiaries	137	411	(7,622)
Income (Loss) Before Income Taxes	(152)	(1,350)	(7,634)
Income tax provision (benefit)	(64)	(46)	8
Loss Attributable to Common Shareholders	(88)	(1,304)	(7,642)
Other Comprehensive Income (Loss)
Pension and other postretirement benefit plans obligations	7	(17)	(1)
Total other comprehensive income (loss)	7	(17)	(1)
Comprehensive Loss	$ (81)	$ (1,321)	$ (7,643)
Weighted Average Common Shares Outstanding, Basic (in shares)	2,463,000,000	1,257,000,000	528,000,000
Weighted Average Common Shares Outstanding, Diluted (in shares)	2,463,000,000	1,257,000,000	528,000,000
Net Loss Per Common Share, Basic (in dollars per share)	$ (0.05)	$ (1.05)	$ (14.50)
Net Loss Per Common Share, Diluted (in dollars per share)	$ (0.05)	$ (1.05)	$ (14.50)
Pension and other postretirement benefit plans obligations, tax	$ 3	$ 7	$ 0
PG&E Corporation \| Administrative service revenue
Revenue	$ 118	$ 127	$ 138

SCHEDULE I _ CONDENSED FINANC_3

SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT (Schedule of Condensed Balance Sheet) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current Assets
Cash and cash equivalents	$ 291	$ 484	$ 1,570
Other	882	1,334
Total current assets	11,077	9,602
Noncurrent Assets
Equipment	98,960	93,894
Accumulated depreciation	(29,134)	(27,758)
Net property, plant, and equipment	69,826	66,136
Operating lease right of use asset	1,234	1,741
TOTAL ASSETS	103,327	97,856
Current Liabilities
Long-term debt, classified as current (includes $18 million and $0 related to VIEs at respective dates)	4,481	28
Operating lease liabilities	468	533
Other current liabilities	2,436	2,256
Total current liabilities	17,427	13,581
Noncurrent Liabilities
Debtor-in-possession financing	38,225	37,288
Operating lease liabilities	810	1,208
Other	4,308	3,848
Total noncurrent liabilities	64,677	63,022
Common Shareholders’ Equity
Common stock, no par value, authorized 3,600,000,000 and 3,600,000,000 shares at respective dates; 1,985,400,540 and 1,984,678,673 shares outstanding at respective dates	35,129	30,224
Reinvested earnings	(9,284)	(9,196)
Accumulated other comprehensive loss	(20)	(27)
Total shareholders' equity	20,971	21,001
TOTAL LIABILITIES AND EQUITY	103,327	97,856
PG&E Corporation
Current Assets
Cash and cash equivalents	126	223
Advances to affiliates	21	48
Income taxes receivable	10	12
Other	12	13
Total current assets	169	296
Noncurrent Assets
Equipment	2	2
Accumulated depreciation	(2)	(2)
Net property, plant, and equipment	0	0
Investments in subsidiaries	30,232	25,244
Other investments	181	186
Operating lease right of use asset	0	3
Deferred income taxes	297	237
Total noncurrent assets	30,710	25,670
TOTAL ASSETS	30,879	25,966
Current Liabilities
Long-term debt, classified as current (includes $18 million and $0 related to VIEs at respective dates)	27	28
Accounts payable – other	200	49
Operating lease liabilities	0	3
Other current liabilities	69	72
Total current liabilities	296	152
Noncurrent Liabilities
Debtor-in-possession financing	4,592	4,624
Operating lease liabilities	0	0
Other	168	191
Total noncurrent liabilities	4,760	4,815
Common Shareholders’ Equity
Common stock, no par value, authorized 3,600,000,000 and 3,600,000,000 shares at respective dates; 1,985,400,540 and 1,984,678,673 shares outstanding at respective dates	35,129	30,224
Reinvested earnings	(9,286)	(9,198)
Accumulated other comprehensive loss	(20)	(27)
Total shareholders' equity	25,823	20,999
TOTAL LIABILITIES AND EQUITY	$ 30,879	$ 25,966

SCHEDULE I _ CONDENSED FINANC_4

SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT (Schedule of Condensed Statement of Cash Flows) (Details) - USD ($) $ in Millions	Aug. 11, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash Flows from Operating Activities
Net Loss		$ (88)	$ (1,304)	$ (7,642)
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income taxes and tax credits, net		1,783	1,097	(2,948)
Reorganization items, net (Note 2)		(73)	1,458	108
Liabilities subject to compromise		0	413	12,222
Net cash provided by (used in) operating activities		2,262	(19,130)	4,816
Cash Flows from Investing Activities
Net cash used in investing activities		(6,905)	(7,748)	(6,378)
Cash Flows From Financing Activities:
Debtor-in-possession credit facility debt issuance costs		0	(6)	(113)
Bridge facility financing fees		0	(73)	0
Repayment of long-term debt		(87)	(764)	0
Intercompany note to PG&E Corporation	$ (145)
Equity Units issued		0	1,304	0
Other		(29)	(40)	(8)
Net cash provided by financing activities		4,323	25,928	1,464
Net change in cash, cash equivalents, and restricted cash		(320)	(950)	(98)
Cash, cash equivalents, and restricted cash at January 1		627	1,577	1,675
Cash, cash equivalents, and restricted cash at December 31		307	627	1,577
Cash paid for:
Interest, net of amounts capitalized		(1,404)	(1,563)	(10)
Income taxes, net		99	0	0
Supplemental disclosures of noncash investing and financing activities
Operating lease liabilities arising from obtaining ROU assets		100	13	2,816
Common stock issued in satisfaction of liabilities		0	8,276	0
Increase to PG&E Corporation common stock and treasury stock in connection with the Share Exchange and Tax Matters Agreement		(4,854)	0	0
Pacific Gas & Electric Co (Utility)
Cash Flows from Operating Activities
Net Loss		138	411	(7,622)
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income taxes and tax credits, net		1,846	1,141	(2,952)
Reorganization items, net (Note 2)		(41)	(90)	97
Liabilities subject to compromise		0	401	12,194
Net cash provided by (used in) operating activities		2,448	(19,047)	4,810
Cash Flows from Investing Activities
Net cash used in investing activities		(7,050)	(7,748)	(6,378)
Cash Flows From Financing Activities:
Debtor-in-possession credit facility debt issuance costs		0	(6)	(97)
Bridge facility financing fees		0	(33)	0
Repayment of long-term debt		(59)	(100)	0
Intercompany note to PG&E Corporation		(145)	0	0
Other		(1)	(42)	(8)
Net cash provided by financing activities		4,379	26,070	1,395
Net change in cash, cash equivalents, and restricted cash		(223)	(725)	(173)
Cash, cash equivalents, and restricted cash at January 1		404	1,129	1,302
Cash, cash equivalents, and restricted cash at December 31		181	404	1,129
Cash paid for:
Interest, net of amounts capitalized		(1,198)	(1,458)	(7)
Income taxes, net		99	0	0
Supplemental disclosures of noncash investing and financing activities
Operating lease liabilities arising from obtaining ROU assets		100	13	2,807
PG&E Corporation
Cash Flows from Operating Activities
Net Loss		(88)	(1,304)	(7,642)
Adjustments to reconcile net income to net cash provided by operating activities:
Stock-based compensation amortization		51	28	43
Equity in earnings (loss) of subsidiaries		(139)	(412)	7,622
Deferred income taxes and tax credits, net		(60)	(50)	0
Reorganization items, net (Note 2)		(32)	1,548	11
Current income taxes receivable/payable		2	0	6
Liabilities subject to compromise		0	12	28
Other		81	97	(62)
Net cash provided by (used in) operating activities		(185)	(81)	6
Cash Flows from Investing Activities
Investment in subsidiaries		0	(12,986)	0
Net cash used in investing activities		0	(12,986)	0
Cash Flows From Financing Activities:
Debtor-in-possession credit facility debt issuance costs		0	0	(16)
Bridge facility financing fees		0	(40)	0
Proceeds from issuance of long-term debt		0	4,660	0
Repayment of long-term debt		(28)	(664)	0
Intercompany note to PG&E Corporation		145	0	0
Common stock issued		0	7,582	85
Equity Units issued		0	1,304	0
Other		(29)	0	0
Net cash provided by financing activities		88	12,842	69
Net change in cash, cash equivalents, and restricted cash		(97)	(225)	75
Cash, cash equivalents, and restricted cash at January 1		223	448	373
Cash, cash equivalents, and restricted cash at December 31		126	223	448
Cash paid for:
Interest, net of amounts capitalized		(207)	(105)	(3)
Income taxes, net		1	0	0
Supplemental disclosures of noncash investing and financing activities
Operating lease liabilities arising from obtaining ROU assets		0	0	9
Common stock issued in satisfaction of liabilities		0	8,276	0
Increase to PG&E Corporation common stock and treasury stock in connection with the Share Exchange and Tax Matters Agreement		$ 4,854	$ 0	$ 0

SCHEDULE II _ CONSOLIDATED VA_2

SCHEDULE II – CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$ 146	$ 43	$ 56
Charged to Costs and Expenses	136	138	0
Charged to Other Accounts	0	0	0
Deductions	111	35	13
Balance at End of Period	$ 171	$ 146	$ 43