PG&E (PCG) 10-Q 26 Jul 23 2023 Q2 Quarterly report Financial data

Cover Page

Cover Page - shares	6 Months Ended
	Jun. 30, 2023	Jul. 19, 2023
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2023
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	300 Lakeside Drive
Entity Address, City or Town	Oakland,
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	94612
City Area Code	415
Local Phone Number	973-1000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Bankruptcy Proceedings, Reporting Current	true
Entity Common Stock, Shares Outstanding (in shares)		2,568,984,928
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q2
Entity Registrant Name	PG&E CORP
Entity Central Index Key	0001004980
Current Fiscal Year End Date	--12-31
Pacific Gas & Electric Co (Utility)
Entity File Number	1-2348
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	94-0742640
Entity Address, Address Line One	300 Lakeside Drive
Entity Address, City or Town	Oakland,
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	94612
City Area Code	415
Local Phone Number	973-7000
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
Entity Shell Company	false
Entity Bankruptcy Proceedings, Reporting Current	true
Entity Common Stock, Shares Outstanding (in shares)		264,374,809
Amendment Flag	false
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% 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

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Operating Revenues
Total operating revenues	$ 5,290	$ 5,118	$ 11,499	$ 10,916
Operating Expenses
Operating and maintenance	2,436	2,291	5,113	5,401
SB 901 securitization charges, net	289	40	562	40
Wildfire-related claims, net of recoveries	(1)	145	(3)	144
Wildfire Fund expense	117	117	234	235
Depreciation, amortization, and decommissioning	997	941	2,074	1,913
Total operating expenses	4,784	4,673	10,364	9,935
Operating Income	506	445	1,135	981
Interest income	143	19	255	27
Interest expense	(640)	(411)	(1,242)	(830)
Other income (expense), net	66	(21)	151	128
Income Before Income Taxes	75	32	299	306
Income tax benefit	(335)	(328)	(683)	(532)
Net Income	410	360	982	838
Preferred stock dividend requirement of subsidiary	4	4	7	7
Income Available for Common Shareholders	$ 406	$ 356	$ 975	$ 831
Weighted Average Common Shares Outstanding, Basic (in shares)	2,019	1,987	2,005	1,987
Weighted Average Common Shares Outstanding, Diluted (in shares)	2,139	2,141	2,137	2,141
Net Income (Loss) Per Common Share, Basic (in dollars per share)	$ 0.20	$ 0.18	$ 0.49	$ 0.42
Net Income (Loss) Per Common Share, Diluted (in dollars per share)	$ 0.19	$ 0.17	$ 0.46	$ 0.39
Electric
Operating Revenues
Total operating revenues	$ 3,852	$ 3,690	$ 7,971	$ 7,848
Operating Expenses
Cost of electricity and natural gas	672	780	1,194	1,282
Natural gas
Operating Revenues
Total operating revenues	1,438	1,428	3,528	3,068
Operating Expenses
Cost of electricity and natural gas	$ 274	$ 359	$ 1,190	$ 920

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Comprehensive Income [Abstract]
Net Income	$ 410	$ 360	$ 982	$ 838
Other Comprehensive Income
Net unrealized gains (losses) on available-for-sale securities (net of taxes of $0, $2, $2 and $2 respectively)	0	(5)	5	(5)
Total other comprehensive income (loss)	0	(5)	5	(5)
Comprehensive Income	410	355	987	833
Preferred stock dividend requirement of subsidiary	4	4	7	7
Comprehensive Income Attributable to Common Shareholders	$ 406	$ 351	$ 980	$ 826

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Comprehensive Income [Abstract]
Net unrealized losses on available for sale securities, tax	$ 0	$ 2	$ 2	$ 2

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Current Assets
Cash and cash equivalents	$ 805	$ 734
Restricted cash (includes $255 million and $201 million related to VIEs at respective dates)	257	213
Accounts receivable
Customers (net of allowance for doubtful accounts of $342 million and $166 million at respective dates) (includes $1.71 billion and $2.47 billion related to VIEs, net of allowance for doubtful accounts of $342 million and $166 million at respective dates)	2,107	2,645
Accrued unbilled revenue (includes $698 million and $1.16 billion related to VIEs at respective dates)	810	1,304
Regulatory balancing accounts	5,383	3,264
Other	1,014	1,624
Regulatory assets	309	296
Inventories
Gas stored underground and fuel oil	55	91
Materials and supplies	833	751
Wildfire Fund asset	460	460
Other	648	1,433
Total current assets	12,681	12,815
Property, Plant, and Equipment
Electric	77,673	74,772
Gas	29,156	28,226
Construction work in progress	4,143	4,137
Financing lease and other	0	19
Total property, plant, and equipment	110,972	107,154
Accumulated depreciation	(32,199)	(30,946)
Net property, plant, and equipment	78,773	76,208
Other Noncurrent Assets
Regulatory assets	15,963	16,443
Customer credit trust	476	745
Nuclear decommissioning trusts	3,524	3,297
Operating lease right of use asset	1,418	1,311
Wildfire Fund asset	4,617	4,847
Income taxes receivable	9	9
Other (includes noncurrent accounts receivable of $4 million and $17 million related to VIEs, net of noncurrent allowance for doubtful accounts of $1 million and $1 million at respective dates)	3,244	2,969
Total other noncurrent assets	29,251	29,621
TOTAL ASSETS	120,705	118,644
Current Liabilities
Short-term borrowings	125	2,055
Long-term debt, classified as current (includes $175 million and $168 million related to VIEs at respective dates)	3,749	2,268
Accounts payable
Trade creditors	2,366	2,888
Regulatory balancing accounts	1,317	1,658
Other	775	778
Operating lease liabilities	136	231
Interest payable (includes $73 million and $116 million related to VIEs at respective dates)	662	626
Wildfire-related claims	1,256	1,912
Other	2,816	3,372
Total current liabilities	13,202	15,788
Noncurrent Liabilities
Long-term debt (includes $10.02 billion and $10.31 billion related to VIEs at respective dates)	50,230	47,742
Regulatory liabilities	18,518	17,630
Pension and other postretirement benefits	226	231
Asset retirement obligations	5,971	5,912
Deferred income taxes	2,422	2,732
Operating lease liabilities	1,473	1,243
Other	4,648	4,291
Total noncurrent liabilities	83,488	79,781
Shareholders’ Equity
Common stock, no par value, authorized 3,600,000,000 and 3,600,000,000 shares at respective dates; 2,062,781,659 and 1,987,784,948 shares outstanding at respective dates	31,628	32,887
Treasury stock, at cost; 127,743,590 and 247,743,590 shares at respective dates	(1,298)	(2,517)
Reinvested earnings	(6,567)	(7,542)
Accumulated other comprehensive loss	0	(5)
Total shareholders’ equity	23,763	22,823
Noncontrolling Interest - Preferred Stock of Subsidiary	252	252
Total equity	24,015	23,075
TOTAL LIABILITIES AND EQUITY	$ 120,705	$ 118,644

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Restricted cash (includes $255 million and $201 million related to VIEs at respective dates)	$ 257	$ 213
Allowance for doubtful accounts	342	166
Customers (net of allowance for doubtful accounts of $342 million and $166 million at respective dates) (includes $1.71 billion and $2.47 billion related to VIEs, net of allowance for doubtful accounts of $342 million and $166 million at respective dates)	2,107	2,645
Accrued unbilled revenue (includes $698 million and $1.16 billion related to VIEs at respective dates)	810	1,304
Long-term debt, classified as current (includes $175 million and $168 million related to VIEs at respective dates)	3,749	2,268
Interest payable (includes $73 million and $116 million related to VIEs at respective dates)	662	626
Long-term debt (includes $10.02 billion and $10.31 billion related to VIEs at respective dates)	$ 50,230	$ 47,742
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)	2,062,781,659	1,987,784,948
Treasury stock, shares at cost (in shares)	127,743,590	247,743,590
Variable Interest Entity, Primary Beneficiary
Restricted cash (includes $255 million and $201 million related to VIEs at respective dates)	$ 255	$ 201
Allowance for doubtful accounts	342	166
Customers (net of allowance for doubtful accounts of $342 million and $166 million at respective dates) (includes $1.71 billion and $2.47 billion related to VIEs, net of allowance for doubtful accounts of $342 million and $166 million at respective dates)	1,710	2,470
Accrued unbilled revenue (includes $698 million and $1.16 billion related to VIEs at respective dates)	698	1,160
Net noncurrent accounts receivable	4	17
Noncurrent allowance for doubtful accounts	1	1
Long-term debt, classified as current (includes $175 million and $168 million related to VIEs at respective dates)	175	168
Interest payable (includes $73 million and $116 million related to VIEs at respective dates)	73	116
Long-term debt (includes $10.02 billion and $10.31 billion related to VIEs at respective dates)	$ 10,020	$ 10,310

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
Cash Flows from Operating Activities
Net Income	$ 982	$ 838
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	2,074	1,913
Bad debt expense	293	76
Allowance for equity funds used during construction	(82)	(82)
Deferred income taxes and tax credits, net	(329)	(156)
Wildfire Fund expense	234	235
Disallowed capital expenditures	7	0
Other	34	428
Effect of changes in operating assets and liabilities:
Accounts receivable	1,589	388
Wildfire-related insurance receivable	347	123
Inventories	(46)	(93)
Accounts payable	145	432
Wildfire-related claims	(656)	(535)
Other current assets and liabilities	(220)	(292)
Regulatory assets, liabilities, and balancing accounts, net	(1,931)	(1,486)
Other noncurrent assets and liabilities	19	(150)
Net cash provided by operating activities	2,460	1,639
Cash Flows from Investing Activities
Capital expenditures	(4,680)	(4,539)
Proceeds from sales and maturities of nuclear decommissioning trust investments	751	1,369
Purchases of nuclear decommissioning trust investments	(802)	(1,341)
Proceeds from sales and maturities of customer credit trust investments	304	0
Purchases of customer credit trust investments	0	(485)
Other	7	16
Net cash used in investing activities	(4,420)	(4,980)
Cash Flows from Financing Activities
Borrowings under credit facilities	5,536	5,235
Repayments under credit facilities	(7,665)	(5,259)
Proceeds from issuance of long-term debt, net of premium, discount and issuance costs of $61 and $35 at respective dates	4,690	4,265
Repayments of long-term debt	(389)	(4,454)
Proceeds from issuance of SB 901 recovery bonds, net of financing fees of $0 and $17 at respective dates	0	3,583
Other	(16)	(21)
Net cash provided by financing activities	2,075	3,349
Net change in cash, cash equivalents, and restricted cash	115	8
Cash, cash equivalents, and restricted cash at January 1	947	307
Cash, cash equivalents, and restricted cash at June 30	1,062	315
Less: Restricted cash and restricted cash equivalents	(257)	(76)
Cash and cash equivalents at June 30	805	239
Cash paid for:
Interest, net of amounts capitalized	(1,068)	(703)
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	860	1,380
Operating lease liabilities arising from obtaining right-of-use assets	208	274
Changes to PG&E Corporation common stock and treasury stock in connection with the Share Exchange and Tax Matters Agreement	(1,219)	0
Forgiveness of DWR loan for performance-based disbursements earned	67	0
Series 2022-A Recovery Bonds
Cash Flows from Financing Activities
Repayments of recovery bonds	(14)	0
SB 901 Securitization
Cash Flows from Financing Activities
Repayments of recovery bonds	$ (67)	$ 0

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
Cash Flows from Financing Activities
Premium, discount, and issuance costs on proceeds from long-term debt	$ 61	$ 35
Financing fees	$ 0	$ 17

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY - USD ($) $ in Millions	Total	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, 2021			1,985,400,540
Beginning balance at Dec. 31, 2021	$ 21,223	$ 20,971	$ 35,129	$ (4,854)	$ (9,284)	$ (20)	$ 252
Beginning balance, treasury (in shares) at Dec. 31, 2021				477,743,590
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	478	478			478
Common stock issued, net (in shares)			2,072,050
Common stock issued, net	(407)	(407)	$ (407)
Treasury stock disposition (in shares)				(40,000,000)
Treasury stock disposition	407	407		$ 407
Stock-based compensation amortization	4	4	$ 4
Preferred stock dividend requirement of subsidiary in arrears	(59)	(59)			(59)
Preferred stock dividend requirement of subsidiary	(2)	(2)			(2)
Ending balance (in shares) at Mar. 31, 2022			1,987,472,590
Ending balance at Mar. 31, 2022	21,644	21,392	$ 34,726	$ (4,447)	(8,867)	(20)	252
Ending balance, treasury (in shares) at Mar. 31, 2022				437,743,590
Beginning balance (in shares) at Dec. 31, 2021			1,985,400,540
Beginning balance at Dec. 31, 2021	21,223	20,971	$ 35,129	$ (4,854)	(9,284)	(20)	252
Beginning balance, treasury (in shares) at Dec. 31, 2021				477,743,590
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	838
Other comprehensive income (loss)	(5)
Ending balance (in shares) at Jun. 30, 2022			1,987,668,220
Ending balance at Jun. 30, 2022	22,019	21,767	$ 34,141	$ (3,838)	(8,511)	(25)	252
Ending balance, treasury (in shares) at Jun. 30, 2022				377,743,590
Beginning balance (in shares) at Mar. 31, 2022			1,987,472,590
Beginning balance at Mar. 31, 2022	21,644	21,392	$ 34,726	$ (4,447)	(8,867)	(20)	252
Beginning balance, treasury (in shares) at Mar. 31, 2022				437,743,590
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	360	360			360
Other comprehensive income (loss)	(5)	(5)				(5)
Common stock issued, net (in shares)			195,630
Common stock issued, net	(609)	(609)	$ (609)
Treasury stock disposition (in shares)				(60,000,000)
Treasury stock disposition	609	609		$ 609
Stock-based compensation amortization	24	24	$ 24
Preferred stock dividend requirement of subsidiary	(4)	(4)			(4)
Ending balance (in shares) at Jun. 30, 2022			1,987,668,220
Ending balance at Jun. 30, 2022	$ 22,019	21,767	$ 34,141	$ (3,838)	(8,511)	(25)	252
Ending balance, treasury (in shares) at Jun. 30, 2022				377,743,590
Beginning balance (in shares) at Dec. 31, 2022	1,987,784,948		1,987,784,948
Beginning balance at Dec. 31, 2022	$ 23,075	22,823	$ 32,887	$ (2,517)	(7,542)	(5)	252
Beginning balance, treasury (in shares) at Dec. 31, 2022	247,743,590			247,743,590
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	$ 572	572			572
Other comprehensive income (loss)	5	5				5
Common stock issued, net (in shares)			7,989,135
Common stock issued, net	(610)	(610)	$ (610)
Treasury stock disposition (in shares)				(60,000,000)
Treasury stock disposition	610	610		$ 610
Stock-based compensation amortization	(63)	(63)	$ (63)
Preferred stock dividend requirement of subsidiary	(3)	(3)			(3)
Ending balance (in shares) at Mar. 31, 2023			1,995,774,083
Ending balance at Mar. 31, 2023	$ 23,586	23,334	$ 32,214	$ (1,907)	(6,973)	0	252
Ending balance, treasury (in shares) at Mar. 31, 2023				187,743,590
Beginning balance (in shares) at Dec. 31, 2022	1,987,784,948		1,987,784,948
Beginning balance at Dec. 31, 2022	$ 23,075	22,823	$ 32,887	$ (2,517)	(7,542)	(5)	252
Beginning balance, treasury (in shares) at Dec. 31, 2022	247,743,590			247,743,590
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	$ 982
Other comprehensive income (loss)	$ 5
Ending balance (in shares) at Jun. 30, 2023	2,062,781,659		2,062,781,659
Ending balance at Jun. 30, 2023	$ 24,015	23,763	$ 31,628	$ (1,298)	(6,567)	0	252
Ending balance, treasury (in shares) at Jun. 30, 2023	127,743,590			127,743,590
Beginning balance (in shares) at Mar. 31, 2023			1,995,774,083
Beginning balance at Mar. 31, 2023	$ 23,586	23,334	$ 32,214	$ (1,907)	(6,973)	0	252
Beginning balance, treasury (in shares) at Mar. 31, 2023				187,743,590
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	410	410			410
Other comprehensive income (loss)	0
Common stock issued, net (in shares)			67,007,576
Common stock issued, net	(609)	(609)	$ (609)
Treasury stock disposition (in shares)				(60,000,000)
Treasury stock disposition	609	609		$ 609
Stock-based compensation amortization	23	23	$ 23
Preferred stock dividend requirement of subsidiary	$ (4)	(4)			(4)
Ending balance (in shares) at Jun. 30, 2023	2,062,781,659		2,062,781,659
Ending balance at Jun. 30, 2023	$ 24,015	$ 23,763	$ 31,628	$ (1,298)	$ (6,567)	$ 0	$ 252
Ending balance, treasury (in shares) at Jun. 30, 2023	127,743,590			127,743,590

CONDENSED CONSOLIDATED STATEM_7

CONDENSED CONSOLIDATED STATEMENTS OF INCOME, UTILITY - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Operating Revenues
Total operating revenues	$ 5,290	$ 5,118	$ 11,499	$ 10,916
Operating Expenses
Operating and maintenance	2,436	2,291	5,113	5,401
SB 901 securitization charges, net	289	40	562	40
Wildfire-related claims, net of recoveries	(1)	145	(3)	144
Wildfire Fund expense	117	117	234	235
Depreciation, amortization, and decommissioning	997	941	2,074	1,913
Total operating expenses	4,784	4,673	10,364	9,935
Operating Income	506	445	1,135	981
Interest income	143	19	255	27
Interest expense	(640)	(411)	(1,242)	(830)
Other income, net	66	(21)	151	128
Income Before Income Taxes	75	32	299	306
Income tax provision (benefit)	(335)	(328)	(683)	(532)
Net Income	410	360	982	838
Preferred stock dividend requirement	4	4
Income Available for Common Shareholders	406	356	975	831
Pacific Gas & Electric Co (Utility)
Operating Revenues
Total operating revenues	5,290	5,118	11,499	10,916
Operating Expenses
Operating and maintenance	2,431	2,210	5,105	5,317
SB 901 securitization charges, net	289	40	562	40
Wildfire-related claims, net of recoveries	(1)	145	(3)	144
Wildfire Fund expense	117	117	234	235
Depreciation, amortization, and decommissioning	997	941	2,074	1,913
Total operating expenses	4,779	4,592	10,356	9,851
Operating Income	511	526	1,143	1,065
Interest income	140	20	250	29
Interest expense	(553)	(353)	(1,073)	(717)
Other income, net	64	132	148	288
Income Before Income Taxes	162	325	468	665
Income tax provision (benefit)	(318)	(275)	(638)	(465)
Net Income	480	600	1,106	1,130
Preferred stock dividend requirement	4	4	7	7
Income Available for Common Shareholders	476	596	1,099	1,123
Electric
Operating Revenues
Total operating revenues	3,852	3,690	7,971	7,848
Operating Expenses
Cost of electricity and natural gas	672	780	1,194	1,282
Electric | Pacific Gas & Electric Co (Utility)
Operating Revenues
Total operating revenues	3,852	3,690	7,971	7,848
Operating Expenses
Cost of electricity and natural gas	672	780	1,194	1,282
Natural gas
Operating Revenues
Total operating revenues	1,438	1,428	3,528	3,068
Operating Expenses
Cost of electricity and natural gas	274	359	1,190	920
Natural gas | Pacific Gas & Electric Co (Utility)
Operating Revenues
Total operating revenues	1,438	1,428	3,528	3,068
Operating Expenses
Cost of electricity and natural gas	$ 274	$ 359	$ 1,190	$ 920

CONDENSED CONSOLIDATED STATEM_8

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME, UTILITY - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Net Income	$ 410	$ 360	$ 982	$ 838
Other Comprehensive Income
Net unrealized gains (losses) on available-for-sale securities (net of taxes of $0, $2, $2, and $2 respectively)	0	(5)	5	(5)
Total other comprehensive income (loss)	0	(5)	5	(5)
Comprehensive Income	410	355	987	833
Pacific Gas & Electric Co (Utility)
Net Income	480	600	1,106	1,130
Other Comprehensive Income
Pension and other post-retirement benefit plans obligations (net of taxes of $0, $0, $0 and $0 respectively)	0	0	0	1
Net unrealized gains (losses) on available-for-sale securities (net of taxes of $0, $2, $2, and $2 respectively)	0	(5)	6	(5)
Total other comprehensive income (loss)	0	(5)	6	(4)
Comprehensive Income	$ 480	$ 595	$ 1,112	$ 1,126

CONDENSED CONSOLIDATED STATEM_9

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Net unrealized losses on available for sale securities, tax	$ 0	$ 2	$ 2	$ 2
Pacific Gas & Electric Co (Utility)
Pension and other postretirement benefit plans obligations, tax	0	0	0	0
Net unrealized losses on available for sale securities, tax	$ 0	$ 2	$ (2)	$ 2

CONDENSED CONSOLIDATED BALANC_3

CONDENSED CONSOLIDATED BALANCE SHEETS, UTILITY - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Current Assets
Cash and cash equivalents	$ 805	$ 734
Restricted cash (includes $255 million and $201 million related to VIEs at respective dates)	257	213
Accounts receivable
Customers (net of allowance for doubtful accounts of $342 million and $166 million at respective dates) (includes $1.71 billion and $2.47 billion related to VIEs, net of allowance for doubtful accounts of $342 million and $166 million at respective dates)	2,107	2,645
Accrued unbilled revenue (includes $698 million and $1.16 billion related to VIEs at respective dates)	810	1,304
Regulatory balancing accounts	5,383	3,264
Other	1,014	1,624
Regulatory assets	309	296
Inventories
Gas stored underground and fuel oil	55	91
Materials and supplies	833	751
Wildfire Fund asset	460	460
Other	648	1,433
Total current assets	12,681	12,815
Property, Plant, and Equipment
Electric	77,673	74,772
Gas	29,156	28,226
Construction work in progress	4,143	4,137
Financing lease	0	19
Total property, plant, and equipment	110,972	107,154
Accumulated depreciation	(32,199)	(30,946)
Net property, plant, and equipment	78,773	76,208
Other Noncurrent Assets
Regulatory assets	15,963	16,443
Customer credit trust	476	745
Nuclear decommissioning trusts	3,524	3,297
Operating lease right of use asset	1,418	1,311
Wildfire Fund asset	4,617	4,847
Income taxes receivable	9	9
Other (includes noncurrent accounts receivable of $4 million and $17 million related to VIEs, net of noncurrent allowance for doubtful accounts of $1 million and $1 million at respective dates)	3,244	2,969
Total other noncurrent assets	29,251	29,621
TOTAL ASSETS	120,705	118,644
Current Liabilities
Short-term borrowings	125	2,055
Long-term debt, classified as current (includes $175 million and $168 million related to VIEs at respective dates)	3,749	2,268
Accounts payable
Trade creditors	2,366	2,888
Regulatory balancing accounts	1,317	1,658
Other	775	778
Operating lease liabilities	136	231
Interest payable (includes $73 million and $116 million related to VIEs at respective dates)	662	626
Wildfire-related claims	1,256	1,912
Other	2,816	3,372
Total current liabilities	13,202	15,788
Noncurrent Liabilities
Long-term debt (includes $10.02 billion and $10.31 billion related to VIEs at respective dates)	50,230	47,742
Regulatory liabilities	18,518	17,630
Pension and other postretirement benefits	226	231
Asset retirement obligations	5,971	5,912
Deferred income taxes	2,422	2,732
Operating lease liabilities	1,473	1,243
Other	4,648	4,291
Total noncurrent liabilities	83,488	79,781
Shareholders’ Equity
Common stock, $5 par value, authorized 800,000,000 shares; 264,374,809 shares outstanding at respective dates	31,628	32,887
Reinvested earnings	(6,567)	(7,542)
Accumulated other comprehensive loss	0	(5)
Total shareholders’ equity	23,763	22,823
TOTAL LIABILITIES AND EQUITY	120,705	118,644
Pacific Gas & Electric Co (Utility)
Current Assets
Cash and cash equivalents	545	609
Restricted cash (includes $255 million and $201 million related to VIEs at respective dates)	256	213
Accounts receivable
Customers (net of allowance for doubtful accounts of $342 million and $166 million at respective dates) (includes $1.71 billion and $2.47 billion related to VIEs, net of allowance for doubtful accounts of $342 million and $166 million at respective dates)	2,107	2,645
Accrued unbilled revenue (includes $698 million and $1.16 billion related to VIEs at respective dates)	810	1,304
Regulatory balancing accounts	5,383	3,264
Other	1,017	1,633
Regulatory assets	309	296
Inventories
Gas stored underground and fuel oil	55	91
Materials and supplies	833	751
Wildfire Fund asset	460	460
Other	647	1,421
Total current assets	12,422	12,687
Property, Plant, and Equipment
Electric	77,673	74,772
Gas	29,156	28,226
Construction work in progress	4,143	4,137
Financing lease	0	18
Total property, plant, and equipment	110,972	107,153
Accumulated depreciation	(32,199)	(30,946)
Net property, plant, and equipment	78,773	76,207
Other Noncurrent Assets
Regulatory assets	15,963	16,443
Customer credit trust	476	745
Nuclear decommissioning trusts	3,524	3,297
Operating lease right of use asset	1,418	1,311
Wildfire Fund asset	4,617	4,847
Income taxes receivable	7	7
Other (includes noncurrent accounts receivable of $4 million and $17 million related to VIEs, net of noncurrent allowance for doubtful accounts of $1 million and $1 million at respective dates)	3,104	2,834
Total other noncurrent assets	29,109	29,484
TOTAL ASSETS	120,304	118,378
Current Liabilities
Short-term borrowings	125	2,055
Long-term debt, classified as current (includes $175 million and $168 million related to VIEs at respective dates)	3,722	2,241
Accounts payable
Trade creditors	2,363	2,886
Regulatory balancing accounts	1,317	1,658
Other	710	747
Operating lease liabilities	136	231
Interest payable (includes $73 million and $116 million related to VIEs at respective dates)	610	573
Wildfire-related claims	1,256	1,912
Other	2,516	3,067
Total current liabilities	12,755	15,370
Noncurrent Liabilities
Long-term debt (includes $10.02 billion and $10.31 billion related to VIEs at respective dates)	45,645	43,155
Regulatory liabilities	18,518	17,630
Pension and other postretirement benefits	156	160
Asset retirement obligations	5,971	5,912
Deferred income taxes	2,825	3,090
Operating lease liabilities	1,473	1,243
Other	4,687	4,334
Total noncurrent liabilities	79,275	75,524
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	29,840	29,280
Reinvested earnings	(3,144)	(3,368)
Accumulated other comprehensive loss	(2)	(8)
Total shareholders’ equity	28,274	27,484
TOTAL LIABILITIES AND EQUITY	$ 120,304	$ 118,378

CONDENSED CONSOLIDATED BALANC_4

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Restricted cash (includes $255 million and $201 million related to VIEs at respective dates)	$ 257	$ 213
Allowance for doubtful accounts	342	166
Customers (net of allowance for doubtful accounts of $342 million and $166 million at respective dates) (includes $1.71 billion and $2.47 billion related to VIEs, net of allowance for doubtful accounts of $342 million and $166 million at respective dates)	2,107	2,645
Accrued unbilled revenue (includes $698 million and $1.16 billion related to VIEs at respective dates)	810	1,304
Long-term debt, classified as current (includes $175 million and $168 million related to VIEs at respective dates)	3,749	2,268
Interest payable (includes $73 million and $116 million related to VIEs at respective dates)	662	626
Long-term debt (includes $10.02 billion and $10.31 billion related to VIEs at respective dates)	$ 50,230	$ 47,742
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)	2,062,781,659	1,987,784,948
Pacific Gas & Electric Co (Utility)
Restricted cash (includes $255 million and $201 million related to VIEs at respective dates)	$ 256	$ 213
Allowance for doubtful accounts	342	166
Customers (net of allowance for doubtful accounts of $342 million and $166 million at respective dates) (includes $1.71 billion and $2.47 billion related to VIEs, net of allowance for doubtful accounts of $342 million and $166 million at respective dates)	2,107	2,645
Accrued unbilled revenue (includes $698 million and $1.16 billion related to VIEs at respective dates)	810	1,304
Long-term debt, classified as current (includes $175 million and $168 million related to VIEs at respective dates)	3,722	2,241
Interest payable (includes $73 million and $116 million related to VIEs at respective dates)	610	573
Long-term debt (includes $10.02 billion and $10.31 billion related to VIEs at respective dates)	$ 45,645	$ 43,155
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
Restricted cash (includes $255 million and $201 million related to VIEs at respective dates)	$ 255	$ 201
Allowance for doubtful accounts	342	166
Customers (net of allowance for doubtful accounts of $342 million and $166 million at respective dates) (includes $1.71 billion and $2.47 billion related to VIEs, net of allowance for doubtful accounts of $342 million and $166 million at respective dates)	1,710	2,470
Accrued unbilled revenue (includes $698 million and $1.16 billion related to VIEs at respective dates)	698	1,160
Net noncurrent accounts receivable	4	17
Noncurrent allowance for doubtful accounts	1	1
Long-term debt, classified as current (includes $175 million and $168 million related to VIEs at respective dates)	175	168
Interest payable (includes $73 million and $116 million related to VIEs at respective dates)	73	116
Long-term debt (includes $10.02 billion and $10.31 billion related to VIEs at respective dates)	10,020	10,310
Variable Interest Entity, Primary Beneficiary | Pacific Gas & Electric Co (Utility)
Restricted cash (includes $255 million and $201 million related to VIEs at respective dates)	255	201
Allowance for doubtful accounts	342	166
Customers (net of allowance for doubtful accounts of $342 million and $166 million at respective dates) (includes $1.71 billion and $2.47 billion related to VIEs, net of allowance for doubtful accounts of $342 million and $166 million at respective dates)	1,710	2,470
Accrued unbilled revenue (includes $698 million and $1.16 billion related to VIEs at respective dates)	698	1,160
Net noncurrent accounts receivable	4	17
Noncurrent allowance for doubtful accounts	1	1
Long-term debt, classified as current (includes $175 million and $168 million related to VIEs at respective dates)	175	168
Interest payable (includes $73 million and $116 million related to VIEs at respective dates)	73	116
Long-term debt (includes $10.02 billion and $10.31 billion related to VIEs at respective dates)	$ 10,020	$ 10,310

CONDENSED CONSOLIDATED STATE_10

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS, UTILITY - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
Cash Flows from Operating Activities
Net Income	$ 982	$ 838
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	2,074	1,913
Bad debt expense	293	76
Allowance for equity funds used during construction	(82)	(82)
Deferred income taxes and tax credits, net	(329)	(156)
Wildfire Fund expense	234	235
Disallowed capital expenditures	7	0
Other	34	428
Effect of changes in operating assets and liabilities:
Accounts receivable	1,589	388
Wildfire-related insurance receivable	347	123
Inventories	(46)	(93)
Accounts payable	145	432
Wildfire-related claims	(656)	(535)
Other current assets and liabilities	(220)	(292)
Regulatory assets, liabilities, and balancing accounts, net	(1,931)	(1,486)
Other noncurrent assets and liabilities	19	(150)
Net cash provided by operating activities	2,460	1,639
Cash Flows from Investing Activities
Capital expenditures	(4,680)	(4,539)
Proceeds from sales and maturities of nuclear decommissioning trust investments	751	1,369
Purchases of nuclear decommissioning trust investments	(802)	(1,341)
Proceeds from sales and maturities of customer credit trust investments	304	0
Purchases of customer credit trust investments	0	(485)
Other	7	16
Net cash used in investing activities	(4,420)	(4,980)
Cash Flows from Financing Activities
Borrowings under credit facilities	5,536	5,235
Repayments under credit facilities	(7,665)	(5,259)
Proceeds from issuance of long-term debt, net of premium, discount and issuance costs of $61 and $35 at respective dates	4,690	4,265
Repayments of long-term debt	(389)	(4,454)
Proceeds from issuance of SB 901 recovery bonds, net of financing fees of $0 and $17 at respective dates	0	3,583
Other	(16)	(21)
Net cash provided by financing activities	2,075	3,349
Net change in cash, cash equivalents, and restricted cash	115	8
Cash, cash equivalents, and restricted cash at January 1	947	307
Cash, cash equivalents, and restricted cash at June 30	1,062	315
Less: Restricted cash and restricted cash equivalents	(257)	(76)
Cash and cash equivalents at June 30	805	239
Supplemental disclosures of cash flow information
Interest, net of amounts capitalized	(1,068)	(703)
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	860	1,380
Operating lease liabilities arising from obtaining right-of-use assets	208	274
Forgiveness of DWR loan for performance-based disbursements earned	67	0
Series 2022-A Recovery Bonds
Cash Flows from Financing Activities
Repayments of recovery bonds	(14)	0
SB 901 Securitization
Cash Flows from Financing Activities
Repayments of recovery bonds	(67)	0
Pacific Gas & Electric Co (Utility)
Cash Flows from Operating Activities
Net Income	1,106	1,130
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	2,074	1,913
Bad debt expense	293	76
Allowance for equity funds used during construction	(82)	(82)
Deferred income taxes and tax credits, net	(278)	(90)
Wildfire Fund expense	234	235
Disallowed capital expenditures	7	0
Other	57	248
Effect of changes in operating assets and liabilities:
Accounts receivable	1,595	309
Wildfire-related insurance receivable	347	123
Inventories	(46)	(93)
Accounts payable	110	406
Wildfire-related claims	(656)	(535)
Other current assets and liabilities	(223)	(288)
Regulatory assets, liabilities, and balancing accounts, net	(1,931)	(1,486)
Other noncurrent assets and liabilities	20	(163)
Net cash provided by operating activities	2,627	1,703
Cash Flows from Investing Activities
Capital expenditures	(4,680)	(4,539)
Proceeds from sales and maturities of nuclear decommissioning trust investments	751	1,369
Purchases of nuclear decommissioning trust investments	(802)	(1,341)
Proceeds from sales and maturities of customer credit trust investments	304	0
Purchases of customer credit trust investments	0	(485)
Proceeds from (repayments of) intercompany note to PG&E Corporation	0	145
Other	7	16
Net cash used in investing activities	(4,420)	(4,835)
Cash Flows from Financing Activities
Borrowings under credit facilities	5,536	5,235
Repayments under credit facilities	(7,665)	(5,259)
Proceeds from issuance of long-term debt, net of premium, discount and issuance costs of $61 and $35 at respective dates	4,690	4,265
Repayments of long-term debt	(375)	(4,441)
Proceeds from issuance of SB 901 recovery bonds, net of financing fees of $0 and $17 at respective dates	0	3,583
Preferred stock dividends paid	(7)	(63)
Common stock dividends paid	(875)	(425)
Equity contribution from PG&E Corporation	560	212
Other	(11)	42
Net cash provided by financing activities	1,772	3,149
Net change in cash, cash equivalents, and restricted cash	(21)	17
Cash, cash equivalents, and restricted cash at January 1	822	181
Cash, cash equivalents, and restricted cash at June 30	801	198
Less: Restricted cash and restricted cash equivalents	(256)	(76)
Cash and cash equivalents at June 30	545	122
Supplemental disclosures of cash flow information
Interest, net of amounts capitalized	(911)	(602)
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	860	1,380
Operating lease liabilities arising from obtaining right-of-use assets	208	274
Forgiveness of DWR loan for performance-based disbursements earned	67	0
Pacific Gas & Electric Co (Utility) | Series 2022-A Recovery Bonds
Cash Flows from Financing Activities
Repayments of recovery bonds	(14)	0
Pacific Gas & Electric Co (Utility) | SB 901 Securitization
Cash Flows from Financing Activities
Repayments of recovery bonds	$ (67)	$ 0

CONDENSED CONSOLIDATED STATE_11

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS, UTILITY (Parenthetical) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
Cash Flows from Financing Activities
Premium, discount, and issuance costs on proceeds from long-term debt	$ 61	$ 35
Financing fees	0	17
Pacific Gas & Electric Co (Utility)
Cash Flows from Financing Activities
Premium, discount, and issuance costs on proceeds from long-term debt	61	35
Financing fees	$ 0	$ 17

CONDENSED CONSOLIDATED STATE_12

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY, UTILITY - USD ($) $ in Millions	Total	Pacific Gas & Electric Co (Utility)	Total Shareholders' Equity	Total Shareholders' Equity Pacific Gas & Electric Co (Utility)	Preferred Stock Pacific Gas & Electric Co (Utility)	Common Stock	Common Stock Pacific Gas & Electric Co (Utility)	Additional Paid-in Capital Pacific Gas & Electric Co (Utility)	Reinvested Earnings	Reinvested Earnings Pacific Gas & Electric Co (Utility)	Accumulated Other Comprehensive Income (Loss)	Accumulated Other Comprehensive Income (Loss) Pacific Gas & Electric Co (Utility)
Beginning balance at Dec. 31, 2021	$ 21,223		$ 20,971	$ 25,610	$ 258	$ 35,129	$ 1,322	$ 28,286	$ (9,284)	$ (4,247)	$ (20)	$ (9)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	478		478	530					478	530
Other comprehensive income (loss)				1								1
Preferred stock dividend requirement of subsidiary in arrears	(59)		(59)	(59)					(59)	(59)
Preferred stock dividend requirement				(2)						(2)
Ending balance at Mar. 31, 2022	21,644		21,392	26,080	258	34,726	1,322	28,286	(8,867)	(3,778)	(20)	(8)
Beginning balance at Dec. 31, 2021	21,223		20,971	25,610	258	35,129	1,322	28,286	(9,284)	(4,247)	(20)	(9)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	838	$ 1,130
Other comprehensive income (loss)	(5)	(4)
Ending balance at Jun. 30, 2022	22,019		21,767	26,458	258	34,141	1,322	28,498	(8,511)	(3,607)	(25)	(13)
Beginning balance at Mar. 31, 2022	21,644		21,392	26,080	258	34,726	1,322	28,286	(8,867)	(3,778)	(20)	(8)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	360	600	360	600					360	600
Other comprehensive income (loss)	(5)	(5)	(5)	(5)							(5)	(5)
Equity contribution				212				212
Dividends, Common Stock				(425)						(425)
Preferred stock dividend requirement				(4)						(4)
Ending balance at Jun. 30, 2022	22,019		21,767	26,458	258	34,141	1,322	28,498	(8,511)	(3,607)	(25)	(13)
Beginning balance at Dec. 31, 2022	23,075		22,823	27,484	258	32,887	1,322	29,280	(7,542)	(3,368)	(5)	(8)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	572		572	626					572	626
Other comprehensive income (loss)	5		5	6							5	6
Equity contribution				310				310
Dividends, Common Stock				(425)						(425)
Preferred stock dividend requirement				(3)						(3)
Ending balance at Mar. 31, 2023	23,586		23,334	27,998	258	32,214	1,322	29,590	(6,973)	(3,170)	0	(2)
Beginning balance at Dec. 31, 2022	23,075		22,823	27,484	258	32,887	1,322	29,280	(7,542)	(3,368)	(5)	(8)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	982	1,106
Other comprehensive income (loss)	5	6
Ending balance at Jun. 30, 2023	24,015		23,763	28,274	258	31,628	1,322	29,840	(6,567)	(3,144)	0	(2)
Beginning balance at Mar. 31, 2023	23,586		23,334	27,998	258	32,214	1,322	29,590	(6,973)	(3,170)	0	(2)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	410	480	410	480					410	480
Other comprehensive income (loss)	0	$ 0
Equity contribution				250				250
Dividends, Common Stock				(450)						(450)
Preferred stock dividend requirement				(4)						(4)
Ending balance at Jun. 30, 2023	$ 24,015		$ 23,763	$ 28,274	$ 258	$ 31,628	$ 1,322	$ 29,840	$ (6,567)	$ (3,144)	$ 0	$ (2)

ORGANIZATION AND BASIS OF PRESE

ORGANIZATION AND BASIS OF PRESENTATION	6 Months Ended
	Jun. 30, 2023
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 quarterly report on Form 10-Q is a combined report of PG&E Corporation and the Utility. PG&E Corporation’s Condensed Consolidated Financial Statements include the accounts of PG&E Corporation, the Utility, and other wholly owned and controlled subsidiaries. The Utility’s Condensed 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 Condensed 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 Condensed Consolidated Financial Statements have been prepared in conformity with GAAP and in accordance with the interim period reporting requirements of Form 10-Q and reflect all adjustments that management believes are necessary for the fair presentation of PG&E Corporation’s and the Utility’s financial condition, results of operations, and cash flows for the periods presented. The information as of December 31, 2022 in the Condensed Consolidated Balance Sheets included in this quarterly report on Form 10-Q was derived from the audited Consolidated Balance Sheets in Item 8 of the 2022 Form 10-K. This quarterly report on Form 10-Q should be read in conjunction with the 2022 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 Condensed 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.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	6 Months Ended
	Jun. 30, 2023
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES 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 Condensed 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. CPUC and FERC rates decouple authorized revenue from the volume of electricity and natural gas sales, so the Utility receives revenue equal to the amounts authorized by the relevant regulatory agencies. As a result, the volume of electricity and natural gas sold does not have a direct impact on PG&E Corporation’s and the Utility’s financial results. 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: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2023 2022 2023 2022 Electric Revenue from contracts with customers Residential $ 1,404 $ 1,213 $ 2,693 $ 2,707 Commercial 1,283 1,252 2,427 2,425 Industrial 375 322 728 672 Agricultural 314 484 469 700 Public street and highway lighting 20 19 39 37 Other, net (1) (121) (77) (78) (90) Total revenue from contracts with customers - electric 3,275 3,213 6,278 6,451 Regulatory balancing accounts (2) 577 477 1,693 1,397 Total electric operating revenue $ 3,852 $ 3,690 $ 7,971 $ 7,848 Natural gas Revenue from contracts with customers Residential $ 691 $ 388 $ 2,574 $ 1,851 Commercial 189 197 702 541 Transportation service only 398 356 842 755 Other, net (1) (257) (88) (410) (267) Total revenue from contracts with customers - gas 1,021 853 3,708 2,880 Regulatory balancing accounts (2) 417 575 (180) 188 Total natural gas operating revenue 1,438 1,428 3,528 3,068 Total operating revenues $ 5,290 $ 5,118 $ 11,499 $ 10,916 (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 June 30, 2023, PG&E Corporation and the Utility 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. During the three and six months ended June 30, 2023, expected credit losses of $154 million and $293 million, respectively, were recorded in Operating and maintenance expense on the Condensed Consolidated Statements of Income for credit losses associated with trade and other receivables. For the three and six months ended June 30, 2022, expected credit losses were $33 million and $76 million, respectively. The portion of expected credit losses that are deemed probable of recovery are deferred to the RUBA, CPPMA, and a FERC regulatory asset. As of June 30, 2023, the RUBA current balancing accounts receivable balance was $228 million, and CPPMA and FERC long-term regulatory asset balances were $4 million and $42 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 10 below. Wildfire Fund receivables risk is related to the Wildfire Fund’s durability, which is a measurement of its 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 their available-for-sale debt securities (i.e., impairment). If such an impairment exists and does not otherwise result in a write-down, then PG&E Corporation and the Utility must determine whether a portion of the impairment is a result of expected credit loss. As of June 30, 2023, expected credit losses for insurance receivables, Wildfire Fund receivables, and available-for-sale debt securities were immaterial. Government Assistance PG&E Corporation and the Utility received various government assistance programs during the six months ended June 30, 2023. PG&E Corporation’s and the Utility’s accounting policy is to apply a grant accounting model by analogy to International Accounting Standards 20, Accounting for Government Grants and Disclosure of Government Assistance . Assembly Bill 180 On June 30, 2022, AB 180 became law. AB 180 authorized the DWR to use up to $75 million to support contracts with the owners of electric generating facilities pending retirement, such as Diablo Canyon, to fund, reimburse or compensate the owner for any costs, expenses or financial commitments incurred to retain the future availability of such generating facilities pending further legislation. The resulting agreement between DWR and the Utility was effective beginning October 1, 2022, and will continue until full disbursement of funds or termination per the agreement. In the event of a termination, the Utility will take reasonable steps to end activities associated with this agreement and will return to DWR any unused funds. The Utility plans to record the income related to government grants as a deduction to Operating and maintenance expense as eligible costs are incurred. DWR Loan Agreement On October 18, 2022, the DWR and the Utility executed a $1.4 billion loan agreement to support the extension of Diablo Canyon, up to approximately $1.1 billion of which could be repaid by funds received from the DOE (see “U.S. DOE’s Civil Nuclear Credit Program” below). Under the loan agreement, the DWR pays the Utility a monthly performance-based disbursement equal to $7 for each MWh generated by Diablo Canyon, effective September 2, 2022. The Utility may use the proceeds of the performance-based disbursements for any business purpose, except as profits or dividends to shareholders or as otherwise prohibited by SB 846. The Utility began earning performance-based disbursements beginning on September 2, 2022 and is eligible to earn performance-based disbursements until the previously-approved retirement dates for Diablo Canyon Unit 1 and Unit 2 (2024 and 2025, respectively). The performance-based disbursements are contingent upon the Utility’s ongoing efforts to pursue extension of and continued safe and reliable operation of Diablo Canyon. The aggregate amount of performance-based disbursements under this agreement will not exceed $300 million. The Utility initially accounts for all disbursements from the DWR loan agreement pursuant to ASC 470, Debt. When there is reasonable assurance that the Utility will have loan disbursements forgiven by the DWR, such as when the Utility earns a performance-based disbursement, the Utility will recognize those forgiven loans as income related to government grants. The Utility plans to record the income related to government grants as a deduction to Operating and maintenance expense in the same period(s) that eligible costs are incurred. As of June 30, 2023, the Condensed Consolidated Financial Statements reflected $245 million in Long-term debt, $15 million in Other current liabilities for income related to eligible costs not yet incurred, and a deduction of $52 million to Operating and maintenance expense for income related to government grants for performance-based disbursements. U.S. DOE’s Civil Nuclear Credit Program On November 17, 2022, the Utility was conditionally awarded a total of approximately $1.1 billion from the DOE related to Diablo Canyon (See “DWR Loan Agreement” above). Final award amounts will be determined following completion of each year of the award period, and amounts awarded over a four-year award period ending in 2026 will be based on actual costs. The Utility will repay its loans outstanding under the DWR Loan Agreement with funding received from the DOE’s Civil Nuclear Credit Program. When there is reasonable assurance that the Utility will receive funding and comply with the conditions of the DOE’s Civil Nuclear Credit Program, the Utility will recognize such funding as income related to government grants. During the three and six months ended June 30, 2023, the Condensed Consolidated Statements of Income reflected $34 million as a deduction to Operating and maintenance expense 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 was created in connection with the Receivables Securitization Program and 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”). The pledged receivables and the corresponding debt are included in Accounts receivable, Accrued unbilled revenue, Other noncurrent assets, and Long-term debt on the Condensed Consolidated Balance Sheets. 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 six months ended June 30, 2023 or is expected to be provided in the future that was not previously contractually required. As of June 30, 2023 and December 31, 2022, the SPV had net accounts receivable of $2.4 billion and $3.6 billion, respectively, and outstanding borrowings of $985 million and $1.2 billion, respectively, under the Receivables Securitization Program. For more information, see Note 4 below. 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 orders for the first and second AB 1054 securitization transactions, the Utility sold its right to receive revenues from the non-bypassable wildfire hardening fixed recovery charges (“Recovery Property”) to PG&E Recovery Funding LLC, which, in turn, issued two separate series of recovery bonds secured by separate Recovery Property. 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 six months ended June 30, 2023 or is expected to be provided in the future that was not previously contractually required. As of June 30, 2023 and December 31, 2022, PG&E Recovery Funding LLC had outstanding borrowings of $1.8 billion, included in Long-term debt and Long-term debt, classified as current on the Condensed Consolidated Balance Sheets. SB 901 Securitization PG&E Wildfire 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 the first and second SB 901 securitization transactions, the Utility sold its right to receive revenues from the non-bypassable fixed recovery charges (“SB 901 Recovery Property”) to PG&E Wildfire Recovery Funding LLC, which, in turn, issued two separate series of recovery bonds secured by separate SB 901 Recovery Property. PG&E Wildfire 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 Wildfire Recovery Funding LLC are decisions made by the servicer of the SB 901 Recovery Property. The Utility is considered the primary beneficiary and consolidates PG&E Wildfire Recovery Funding LLC as it acts in this role as servicer. No additional financial support was provided to PG&E Wildfire Recovery Funding LLC during the six months ended June 30, 2023 or is expected to be provided in the future that was not previously contractually required. As of June 30, 2023 and December 31, 2022, PG&E Wildfire Recovery Funding LLC had outstanding borrowings of $7.4 billion and $7.5 billion, respectively, included in Long-term debt and Long-term debt, classified as current on the Condensed Consolidated Balance Sheets. For more information, see Note 5 below. Non-Consolidated VIEs Power Purchase Agreement s 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 as of June 30, 2023, 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 or 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 as of June 30, 2023, it did not consolidate any of them. The Lakeside Building BA2 300 Lakeside LLC, a wholly owned subsidiary of TMG Bay Area Investments II, LLC, and the Utility are parties to an office lease agreement for approximately 910,000 rentable square feet of space within the Lakeside Building which serves as the Utility’s principal administrative headquarters. BA2 300 Lakeside LLC is considered a VIE because the group that holds the equity investment at risk lacks the right to receive the expected residual returns of the entity due to a fixed-price purchase option covering more than 50% of the fair value of the assets held by the entity. The most significant activities that impact the economic performance of BA2 300 Lakeside LLC are decisions related to significant maintenance and remarketing of the property. The Utility is not considered the primary beneficiary and does not consolidate BA2 300 Lakeside LLC as it does not have any decision-making rights associated with these activities. The Utility’s financial obligation is limited to issued letters of credit as well as the amounts it pays for base rent and certain costs, per the office lease agreement. For more information, see “Oakland Headquarters Lease and Purchase” in Note 11 below. Contributions to the Wildfire Fund Established Pursuant to AB 1054 PG&E Corporation and the Utility account for contributions to the Wildfire Fund by capitalizing an asset, amortizing to periods ratably based on an estimated period of coverage, and incrementally adjusting for accelerated amortization as the level of coverage declines, as further described below. However, AB 1054 did not specify a period of coverage for the Wildfire Fund; therefore, this accounting treatment is subject to significant accounting judgments and estimates. Since the inception of the Wildfire Fund, PG&E Corporation and the Utility have estimated a period of coverage of 15 years. In estimating the period of coverage, PG&E Corporation and the Utility used a dataset of historical, publicly available fire-loss data caused by electrical equipment to create Monte Carlo simulations of expected loss. The number of years of historic fire-loss data and the effectiveness of mitigation efforts by the California electric utility companies are significant assumptions used to estimate the period of coverage. Other assumptions include the estimated costs to settle wildfire claims for participating electric utilities including the Utility, the CPUC’s determinations of whether costs were just and reasonable in cases of electric utility-caused wildfires and amounts required to be reimbursed to the Wildfire Fund, the impacts of climate change, the amount 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 participating electric utilities. These assumptions create a high degree of uncertainty for the estimated useful life of the Wildfire Fund. PG&E Corporation and the Utility evaluate and, where appropriate, update all assumptions quarterly. Changes in any of the assumptions could materially impact the estimated period of coverage. PG&E Corporation and the Utility assess the Wildfire Fund asset for acceleration of the amortization of the asset in the event that it is probable that a participating utility’s electrical equipment will be found to be the substantial cause of a catastrophic wildfire. As of June 30, 2023, PG&E Corporation and the Utility recorded $193 million in Other current liabilities, $939 million in Other non-current liabilities, $460 million in Current assets - Wildfire Fund asset, and $4.6 billion in Non-current assets - Wildfire Fund asset in the Condensed Consolidated Balance Sheets. During the three months ended June 30, 2023 and 2022, the Utility recorded amortization and accretion expense of $117 million and $117 million, respectively. During the six months ended June 30, 2023 and 2022, the Utility recorded amortization and accretion expense of $234 million and $235 million, respectively. The amortization of the asset, accretion of the liability, and applicable acceleration of the amortization of the asset is reflected in Wildfire Fund expense in the Condensed Consolidated Statements of Income. As of June 30, 2023, PG&E Corporation and the Utility had recorded $175 million in Other noncurrent assets for Wildfire Fund receivables related to the 2021 Dixie fire. For more information, see “Wildfire Fund under AB 1054” in Note 10 below. Pension and Other Post-Retirement Benefits 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. The net periodic benefit costs reflected in PG&E Corporation’s Condensed Consolidated Financial Statements for the three and six months ended June 30, 2023 and 2022 were as follows: Pension Benefits Other Benefits Three Months Ended June 30, (in millions) 2023 2022 2023 2022 Service cost for benefits earned (1) $ 95 $ 144 $ 9 $ 16 Interest cost 229 173 19 14 Expected return on plan assets (246) (298) (33) (33) Amortization of prior service cost (1) (1) — 1 Amortization of net actuarial (gain) loss — 1 (4) (10) Net periodic benefit cost 77 19 (9) (12) Regulatory account transfer (2) (6) 64 — — Total $ 71 $ 83 $ (9) $ (12) (1) A portion of service costs is capitalized pursuant to GAAP. (2) The Utility recorded these amounts to a regulatory account since they are probable of recovery from, or refund to, customers in future rates. Pension Benefits Other Benefits Six Months Ended June 30, (in millions) 2023 2022 2023 2022 Service cost for benefits earned (1) $ 190 $ 288 $ 19 $ 31 Interest cost 457 346 37 27 Expected return on plan assets (491) (595) (66) (65) Amortization of prior service cost (2) (2) 1 3 Amortization of net actuarial (gain) loss — 1 (9) (20) Net periodic benefit cost 154 38 (18) (24) Regulatory account transfer (2) (13) 127 — — Total $ 141 $ 165 $ (18) $ (24) (1) A portion of service costs is capitalized pursuant to GAAP. (2) The Utility recorded these amounts to a regulatory account since they are probable of recovery from, or refund to, customers in future rates. Non-service costs are reflected in Other income, net on the Condensed Consolidated Statements of Income. Service costs are reflected in Operating and maintenance on the Condensed Consolidated Statements of Income. There was no material difference between PG&E Corporation and the Utility for the information disclosed above. Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (Loss) The changes, net of income tax, in PG&E Corporation’s accumulated other comprehensive income (loss) consisted of the following: Pension Other Customer Credit Trust Total (in millions, net of income tax) Three Months Ended June 30, 2023 Beginning balance $ (12) $ 18 $ (1) $ 5 Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1, $0 and $0, respectively) — — — — Amortization of net actuarial gain (net of taxes of $0, $1 and $0, respectively) — (3) — (3) Regulatory account transfer (net of taxes of $1, $1 and $0, respectively) — 3 — 3 Net current period other comprehensive gain — — — — Ending balance $ (12) $ 18 $ (1) $ 5 (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. See the “Pension and Other Post-Retirement Benefits” table above for additional details. Pension Benefits Other Customer Credit Trust Total (in millions, net of income tax) Three Months Ended June 30, 2022 Beginning balance $ (33) $ 18 $ — $ (15) Other comprehensive income before reclassification Loss on investments (net of taxes of $0, $0 and $2, respectively) — — (5) (5) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $0, $0 and $0, respectively) (1) 1 — — Amortization of net actuarial (gain) loss (net of taxes of $0, $3 and $0, respectively) 1 (7) — (6) Regulatory account transfer (net of taxes of $0, $3 and $0, respectively) — 6 — 6 Net current period other comprehensive loss — — (5) (5) Ending balance $ (33) $ 18 $ (5) $ (20) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. See the “Pension and Other Post-Retirement Benefits” table above for additional details. Pension Other Customer Credit Trust Total (in millions, net of income tax) Six Months Ended June 30, 2023 Beginning balance $ (12) $ 18 $ (6) $ — Other comprehensive income before reclassification Gain on investments (net of taxes of $0, $0 and $2, respectively) — — 5 5 Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1, $0 and $0, respectively) (1) 1 — — Amortization of net actuarial gain (net of taxes of $0, $2 and $0, respectively) — (7) — (7) Regulatory account transfer (net of taxes of $1, $2 and $0, respectively) 1 6 — 7 Net current period other comprehensive gain — — 5 5 Ending balance $ (12) $ 18 $ (1) $ 5 (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. See the “Pension and Other Post-Retirement Benefits” table above for additional details. Pension Other Customer Credit Trust Total (in millions, net of income tax) Six Months Ended June 30, 2022 Beginning balance $ (33) $ 18 $ — $ (15) Other comprehensive income before reclassification Loss on investments (net of taxes of $0, $0 and $2, respectively) — — (5) (5) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $0, $1 and$0, respectively) (2) 2 — — Amortization of net actuarial (gain) loss (net of taxes of $0, $6 and $0, respectively) 1 (14) — (13) Regulatory account transfer (net of taxes of $0, $5 and $0, respectively) 1 12 — 13 Net current period other comprehensive loss — — (5) (5) Ending balance $ (33) $ 18 $ (5) $ (20) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. See the “Pension and Other Post-Retirement Benefits” table above for additional details. There was no material difference between PG&E Corporation and the Utility for the information disclosed above.

REGULATORY ASSETS, LIABILITIES,

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	6 Months Ended
	Jun. 30, 2023
Regulated Operations [Abstract]
REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS Regulatory Assets Current Regulatory Assets As of June 30, 2023 and December 31, 2022, the Utility had current regulatory assets of $309 million and $296 million, respectively. As of June 30, 2023, current regulatory assets included approximately $100 million of deferred depreciation, interest, and tax expense related to 2022 rate base that were determined to be probable of recovery through the 2023 GRC. Long-Term Regulatory Assets Long-term regulatory assets are comprised of the following: Balance at (in millions) June 30, 2023 December 31, 2022 Pension benefits (1) $ 109 $ 120 Environmental compliance costs 1,204 1,193 Utility retained generation (2) 63 86 Price risk management 164 177 Catastrophic event memorandum account (3) 1,272 1,085 Wildfire expense memorandum account (4) 468 439 Fire hazard prevention memorandum account (5) 86 79 Fire risk mitigation memorandum account (6) 23 65 Wildfire mitigation plan memorandum account (7) 654 756 Deferred income taxes (8) 3,100 2,730 Insurance premium costs (9) 11 99 Wildfire mitigation balancing account (10) 252 327 Vegetation management balancing account (11) 1,652 2,276 COVID-19 pandemic protection memorandum accounts (12) 18 26 Microgrid memorandum account (13) 141 213 Financing costs (14) 203 211 SB 901 securitization (15) 5,296 5,378 AROs in excess of recoveries (16) — 120 Other 1,247 1,063 Total long-term regulatory assets $ 15,963 $ 16,443 (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. The increase in the CEMA regulatory asset from December 31, 2022 to June 30, 2023 is primarily due to costs incurred for repair and restoration work performed related to an increase in declared winter storm events in the Utility’s service area. As of June 30, 2023 and December 31, 2022, $45 million and $44 million in COVID-19 related costs were recorded to CEMA regulatory assets, respectively. Recovery of CEMA costs is subject to CPUC review and approval. (4) Represents incremental wildfire claims and outside legal expenses related to the 2021 Dixie fire and the 2022 Mosquito fire. 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 incremental costs associated with fire risk mitigation. Recovery of FRMMA costs is subject to CPUC review and approval. (7) Includes costs associated with the 2020 WMP for the period of January 1, 2020 through December 31, 2020, the 2021 WMP for the period of January 1, 2021 through December 31, 2021, the 2022 WMP for the period of January 1, 2022 through December 31, 2022, and the 2023 WMP for the period of January 1, 2023 through June 30, 2023. Also includes the noncurrent portion of costs associated with the 2019 WMP that were approved for recovery per the 2020 WMCE final decision. 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 of January 1, 2020 through June 30, 2023. The noncurrent balance represents costs above 115% of adopted revenue requirements, which are subject to CPUC review and approval. (11) Includes costs associated with certain vegetation management activities for the period of January 1, 2020 through June 30, 2023. The noncurrent balance represents costs above 120% of adopted revenue requirements, which are subject to CPUC review and approval. (12) Includes costs associated with customer protections, including higher uncollectible costs related to the moratorium on electric and gas service disconnections program implementation costs, and higher accounts receivable financing costs for the period of March 4, 2020 to September 30, 2021. As of June 30, 2023, the Utility had recorded uncollectibles in the amount of $4 million for small business customers. The remaining $14 million is associated with program costs and higher accounts receivable financing costs. As of December 31, 2022, the Utility had recorded uncollectibles in the amount of $4 million for small business customers. The remaining $22 million is associated with program costs and higher accounts receivable financing costs. Recovery of CPPMA costs is subject to CPUC review and approval. (13) Includes costs associated with temporary generation, infrastructure upgrades, and community grid enablement programs associated with the implementation of microgrids. Amounts incurred are subject to CPUC review and approval. (14) Includes costs associated with long-term debt financing deemed recoverable under ASC 980 more than twelve months from the current date. These costs and their amortization period are reviewable and approved in the Utility’s cost of capital or other regulatory filings. (15) In connection with the SB 901 securitization, the CPUC authorized the issuance of one or more series of recovery bonds in connection with the post-emergence transaction to finance $7.5 billion of claims associated with the 2017 Northern California wildfires. The balance represents PG&E Wildfire Recovery Funding LLC’s right to recover $7.5 billion in wildfire claims costs associated with the 2017 Northern California wildfires, partially offset by the $2.0 billion in required upfront shareholder contributions to the customer credit trust, net of amortization since inception. The recovery bonds are being paid through fixed recovery charges, which are designed to recover the full scheduled principal amount of the recovery bonds along with any associated interest and financing costs. See Note 5 below. (16) 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 asset also represents the deferral of realized and unrealized gains and losses on these nuclear decommissioning trust investments. See Note 9 below. Regulatory Liabilities Long-term regulatory liabilities are comprised of the following: Balance at (in millions) June 30, 2023 December 31, 2022 Cost of removal obligations (1) $ 8,023 $ 7,773 Public purpose programs (2) 1,225 1,062 Employee benefit plans (3) 918 904 Transmission tower wireless licenses (4) 421 430 SFGO sale (5) 224 264 SB 901 securitization (6) 6,127 5,800 Wildfire self-insurance (7) 200 — Other 1,380 1,397 Total long-term regulatory liabilities $ 18,518 $ 17,630 (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 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. (3) Represents cumulative differences between incurred costs and amounts collected in rates for post-retirement medical, post-retirement life and long-term disability plans. (4) Represents the portion of the net proceeds received from the sale of transmission tower wireless licenses that will be returned to customers through 2042. Of the $421 million, $294 million will be refunded to FERC-jurisdictional customers, and $127 million will be refunded to CPUC-jurisdictional customers. (5) 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 that began in 2022. (6) In connection with the SB 901 securitization, the Utility is required to return up to $7.59 billion of certain shareholder tax benefits to customers via periodic bill credits over the life of the recovery bonds. The balance reflects qualifying shareholder tax benefits that PG&E Corporation is obligated to contribute to the customer credit trust, net of amortization since inception, and is expected to increase as additional qualifying amounts are recognized, including when the Fire Victim Trust sells additional shares. PG&E Corporation will continue to separately recognize tax benefits within income tax expense on the income statement when the Fire Victim Trust sells additional shares. See Note 5 below. (7) Represents amounts received from customers designated for wildfire self-insurance. See Note 10 below. Regulatory Balancing Accounts Current regulatory balancing accounts receivable and payable are comprised of the following: Balance at (in millions) June 30, 2023 December 31, 2022 Electric distribution (1) $ 1,289 $ 448 Electric transmission (2) 117 96 Gas distribution and transmission (3) 62 72 Energy procurement (4) 1,032 684 Public purpose programs (5) 300 358 Fire hazard prevention memorandum account (6) 129 — Wildfire mitigation plan memorandum account (7) 78 — Wildfire mitigation balancing account (8) 96 2 Vegetation management balancing account (9) 872 137 Insurance premium costs (10) 268 602 Residential uncollectibles balancing accounts (11) 228 126 Catastrophic event memorandum account (12) 332 144 Other 580 595 Total regulatory balancing accounts receivable $ 5,383 $ 3,264 Balance at (in millions) June 30, 2023 December 31, 2022 Electric transmission (2) $ 222 $ 228 Gas distribution and transmission (3) 449 66 Energy procurement (4) 8 428 Public purpose programs (5) 257 272 SFGO sale 75 152 Other 306 512 Total regulatory balancing accounts payable $ 1,317 $ 1,658 (1) The electric distribution accounts track the collection of revenue requirements approved in the GRC and other proceedings. (2) The electric transmission accounts track recovery of costs related to the transmission of electricity approved in the FERC TO rate cases. (3) The gas distribution and transmission accounts track the collection of revenue requirements approved in the GRC and the GT&S rate case and other proceedings. (4) Energy procurement balancing accounts track recovery of costs related to the procurement of electricity and other revenue requirements approved by the CPUC for recovery in procurement-related balancing accounts, including any environmental compliance-related activities. (5) The Public purpose programs balancing accounts are primarily used to record and recover authorized revenue requirements for CPUC-mandated programs such as energy efficiency. (6) The FHPMA tracks costs associated with the implementation of regulations and requirements adopted to protect the public from potential fire hazards approved for cost recovery in the 2020 WMCE final decision. (7) The WMPMA tracks costs associated with the 2019 WMP which were approved for cost recovery in the 2020 WMCE final decision. (8) The WMBA tracks costs associated with wildfire mitigation revenue requirement activities approved for cost recovery. (9) The VMBA tracks routine and enhanced vegetation management activities approved for cost recovery. (10) 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, as of June 30, 2023, and December 31, 2022 there were $7 million and $48 million, respectively, in insurance premium costs recorded in Current regulatory assets. (11) The RUBA tracks costs associated with customer protections, including higher uncollectible costs related to a moratorium on electric and gas service disconnections for residential customers. (12) The CEMA tracks costs associated with responding to catastrophic events that have been declared a disaster or state of emergency by competent federal or state authorities approved for cost recovery in the 2018 CEMA and 2020 WMCE final decisions. For more information, see Note 4 of the Notes to the Consolidated Financial Statements in Item 8 of the 2022 Form 10-K.

DEBT

DEBT	6 Months Ended
	Jun. 30, 2023
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 as of June 30, 2023: (in millions) Termination Maximum Facility Limit Loans Outstanding Letters of Credit Outstanding Facility Utility revolving credit facility June 2028 $ 4,400 (1) $ — $ (697) $ 3,703 Utility Receivables Securitization Program (2) June 2025 985 (3) (985) — — (3) PG&E Corporation revolving credit facility June 2026 500 — — 500 Total credit facilities $ 5,885 $ (985) $ (697) $ 4,203 (1) Includes a $2.0 billion letter of credit sublimit. (2) For more information on the Receivables Securitization Program, see “Variable Interest Entities” in Note 2 above. (3) 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 limit fluctuates between $1.25 billion and $1.5 billion depending on the periods set forth in the transaction documents. Further, 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. Utility On April 18, 2023, the Utility amended its existing term loan agreement to extend the maturity of the $125 million 364-day tranche loan thereunder from April 19, 2023 to April 16, 2024. The 364-day tranche loan bears interest based on the Utility’s election of either (1) Term SOFR (plus a 0.10% credit spread adjustment) plus an applicable margin of 1.375%, or (2) the alternative base rate plus an applicable margin of 0.375%. On June 9, 2023, the Utility entered into an amendment to the Utility Receivables Securitization Program to, among other things, extend the scheduled termination date from September 30, 2024 to June 9, 2025 and increase the low end of the facility limit from $1.0 billion to $1.25 billion. On June 22, 2023, the Utility amended its existing revolving credit agreement to, among other things, (i) extend the maturity date to June 22, 2028 (subject to two one-year extensions at the option of the Utility), (ii) increase the maximum letter of credit sublimit to $2.0 billion, and (iii) increase the uncommitted incremental facility to up to $1.0 billion. PG&E Corporation On June 22, 2023, PG&E Corporation amended its existing revolving credit agreement to, among other things, extend the maturity date to June 22, 2026 (subject to two one-year extensions at the option of PG&E Corporation). Long-Term Debt Issuances and Redemptions Utility On January 6, 2023, the Utility completed the sale of (i) $750 million aggregate principal amount of 6.150% First Mortgage Bonds due 2033 and (ii) $750 million aggregate principal amount of 6.750% First Mortgage Bonds due 2053. The proceeds were used for the repayment of borrowings outstanding under the Utility’s revolving credit facility pursuant to the Utility Revolving Credit Agreement . On March 30, 2023, the Utility completed the sale of $750 million aggregate principal amount of 6.70% First Mortgage Bonds due 2053. The Utility intends to disburse or allocate an amount equal to the net proceeds to finance or refinance, in whole or in part, new or existing eligible green projects and eligible social projects. Pending full disbursement or allocation of an amount equal to the net proceeds from this offering to finance or refinance eligible projects, the Utility expects to use the net proceeds for the repayment of borrowings outstanding under the Utility Revolving Credit Agreement. Pursuant to the financing order for the SB 901 securitization transactions, the Utility sold its right to receive revenues from the SB 901 Recovery Property to PG&E Wildfire Recovery Funding LLC, which, in turn, issued the recovery bonds secured by separate fixed recovery charges and separate SB 901 Recovery Property. The fixed recovery charges are designed to recover the full scheduled principal amount of the applicable series of recovery bonds along with any associated interest and financing costs. In the context of the customer harm threshold decision, which is intended to insulate customers from the fixed recovery charge, there is a customer credit which is designed to equal the recovery bond principal, interest, and financing costs over the life of the recovery bonds. The customer credit is funded by the customer credit trust (see Note 9 below). The fixed recovery charges and customer credits are presented on a net basis in Operating Revenues in the Condensed Consolidated Statements of Income and had no net impact on Operating Revenues for the six months ended June 30, 2023. Upon issuance of the Series 2022-A Recovery Bonds in May 2022 (“inception”), the Utility recorded a $5.5 billion SB 901 securitization regulatory asset reflecting PG&E Wildfire Recovery Funding LLC’s right to recover $7.5 billion in wildfire claims costs associated with the 2017 Northern California wildfires, partially offset by the $2.0 billion in required upfront shareholder contributions to the customer credit trust. Of the $2.0 billion in required upfront shareholder contributions, $1.0 billion was contributed to the customer credit trust in 2022, and $1.0 billion is required to be contributed in 2024. The Utility also recorded a $5.54 billion SB 901 securitization regulatory liability at inception, which represents certain shareholder tax benefits the Utility had previously recognized that will be returned to customers. As the Fire Victim Trust sells the remaining shares it holds of PG&E Corporation common stock, the SB 901 securitization regulatory liability will increase, reflecting the recognition of additional income tax benefits, up to $7.59 billion. As these tax benefits are monetized, they will be contributed to the customer credit trust. The Utility expects to amortize the SB 901 securitization regulatory asset and liability over the life of the recovery bonds, with such amortization reflected in Operating and maintenance expense in the Consolidated Statements of Income. During the three months ended June 30, 2023, the Utility recorded SB 901 securitization charges, net, of $289 million for tax benefits realized within income tax expense in the current year related to the Fire Victim Trust’s sale of PG&E Corporation common stock (see Note 6 below) and $71 million for amortization of the regulatory asset and liability in the Condensed Consolidated Statements of Income. During the six months ended June 30, 2023, the Utility recorded SB 901 securitization charges, net, of $562 million for tax benefits realized within income tax expense in the current year related to the Fire Victim Trust’s sale of PG&E Corporation common stock (see Note 6 below) and $158 million for amortization of the regulatory asset and liability in the Condensed Consolidated Statements of Income. SB 901 securitization charges are expected to increase in future periods, up to $2.09 billion in total, as the tax benefits described above are recognized and recorded within Deferred income taxes. The following tables illustrate the changes in the SB 901 securitization’s impact on the Utility’s regulatory assets and liabilities since December 31, 2022: SB 901 securitization regulatory asset (in millions) Balance at December 31, 2022 $ 5,378 Amortization (82) Balance at June 30, 2023 $ 5,296 SB 901 securitization regulatory liability (in millions) Balance at December 31, 2022 $ (5,800) Amortization 240 Additions (1) (567) Balance at June 30, 2023 $ (6,127)

SB 901 SECURITIZATION AND CUSTO

SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST	6 Months Ended
	Jun. 30, 2023
Debt Disclosure [Abstract]
SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST	DEBT Credit Facilities The following table summarizes PG&E Corporation’s and the Utility’s outstanding borrowings and availability under their credit facilities as of June 30, 2023: (in millions) Termination Maximum Facility Limit Loans Outstanding Letters of Credit Outstanding Facility Utility revolving credit facility June 2028 $ 4,400 (1) $ — $ (697) $ 3,703 Utility Receivables Securitization Program (2) June 2025 985 (3) (985) — — (3) PG&E Corporation revolving credit facility June 2026 500 — — 500 Total credit facilities $ 5,885 $ (985) $ (697) $ 4,203 (1) Includes a $2.0 billion letter of credit sublimit. (2) For more information on the Receivables Securitization Program, see “Variable Interest Entities” in Note 2 above. (3) 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 limit fluctuates between $1.25 billion and $1.5 billion depending on the periods set forth in the transaction documents. Further, 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. Utility On April 18, 2023, the Utility amended its existing term loan agreement to extend the maturity of the $125 million 364-day tranche loan thereunder from April 19, 2023 to April 16, 2024. The 364-day tranche loan bears interest based on the Utility’s election of either (1) Term SOFR (plus a 0.10% credit spread adjustment) plus an applicable margin of 1.375%, or (2) the alternative base rate plus an applicable margin of 0.375%. On June 9, 2023, the Utility entered into an amendment to the Utility Receivables Securitization Program to, among other things, extend the scheduled termination date from September 30, 2024 to June 9, 2025 and increase the low end of the facility limit from $1.0 billion to $1.25 billion. On June 22, 2023, the Utility amended its existing revolving credit agreement to, among other things, (i) extend the maturity date to June 22, 2028 (subject to two one-year extensions at the option of the Utility), (ii) increase the maximum letter of credit sublimit to $2.0 billion, and (iii) increase the uncommitted incremental facility to up to $1.0 billion. PG&E Corporation On June 22, 2023, PG&E Corporation amended its existing revolving credit agreement to, among other things, extend the maturity date to June 22, 2026 (subject to two one-year extensions at the option of PG&E Corporation). Long-Term Debt Issuances and Redemptions Utility On January 6, 2023, the Utility completed the sale of (i) $750 million aggregate principal amount of 6.150% First Mortgage Bonds due 2033 and (ii) $750 million aggregate principal amount of 6.750% First Mortgage Bonds due 2053. The proceeds were used for the repayment of borrowings outstanding under the Utility’s revolving credit facility pursuant to the Utility Revolving Credit Agreement . On March 30, 2023, the Utility completed the sale of $750 million aggregate principal amount of 6.70% First Mortgage Bonds due 2053. The Utility intends to disburse or allocate an amount equal to the net proceeds to finance or refinance, in whole or in part, new or existing eligible green projects and eligible social projects. Pending full disbursement or allocation of an amount equal to the net proceeds from this offering to finance or refinance eligible projects, the Utility expects to use the net proceeds for the repayment of borrowings outstanding under the Utility Revolving Credit Agreement. Pursuant to the financing order for the SB 901 securitization transactions, the Utility sold its right to receive revenues from the SB 901 Recovery Property to PG&E Wildfire Recovery Funding LLC, which, in turn, issued the recovery bonds secured by separate fixed recovery charges and separate SB 901 Recovery Property. The fixed recovery charges are designed to recover the full scheduled principal amount of the applicable series of recovery bonds along with any associated interest and financing costs. In the context of the customer harm threshold decision, which is intended to insulate customers from the fixed recovery charge, there is a customer credit which is designed to equal the recovery bond principal, interest, and financing costs over the life of the recovery bonds. The customer credit is funded by the customer credit trust (see Note 9 below). The fixed recovery charges and customer credits are presented on a net basis in Operating Revenues in the Condensed Consolidated Statements of Income and had no net impact on Operating Revenues for the six months ended June 30, 2023. Upon issuance of the Series 2022-A Recovery Bonds in May 2022 (“inception”), the Utility recorded a $5.5 billion SB 901 securitization regulatory asset reflecting PG&E Wildfire Recovery Funding LLC’s right to recover $7.5 billion in wildfire claims costs associated with the 2017 Northern California wildfires, partially offset by the $2.0 billion in required upfront shareholder contributions to the customer credit trust. Of the $2.0 billion in required upfront shareholder contributions, $1.0 billion was contributed to the customer credit trust in 2022, and $1.0 billion is required to be contributed in 2024. The Utility also recorded a $5.54 billion SB 901 securitization regulatory liability at inception, which represents certain shareholder tax benefits the Utility had previously recognized that will be returned to customers. As the Fire Victim Trust sells the remaining shares it holds of PG&E Corporation common stock, the SB 901 securitization regulatory liability will increase, reflecting the recognition of additional income tax benefits, up to $7.59 billion. As these tax benefits are monetized, they will be contributed to the customer credit trust. The Utility expects to amortize the SB 901 securitization regulatory asset and liability over the life of the recovery bonds, with such amortization reflected in Operating and maintenance expense in the Consolidated Statements of Income. During the three months ended June 30, 2023, the Utility recorded SB 901 securitization charges, net, of $289 million for tax benefits realized within income tax expense in the current year related to the Fire Victim Trust’s sale of PG&E Corporation common stock (see Note 6 below) and $71 million for amortization of the regulatory asset and liability in the Condensed Consolidated Statements of Income. During the six months ended June 30, 2023, the Utility recorded SB 901 securitization charges, net, of $562 million for tax benefits realized within income tax expense in the current year related to the Fire Victim Trust’s sale of PG&E Corporation common stock (see Note 6 below) and $158 million for amortization of the regulatory asset and liability in the Condensed Consolidated Statements of Income. SB 901 securitization charges are expected to increase in future periods, up to $2.09 billion in total, as the tax benefits described above are recognized and recorded within Deferred income taxes. The following tables illustrate the changes in the SB 901 securitization’s impact on the Utility’s regulatory assets and liabilities since December 31, 2022: SB 901 securitization regulatory asset (in millions) Balance at December 31, 2022 $ 5,378 Amortization (82) Balance at June 30, 2023 $ 5,296 SB 901 securitization regulatory liability (in millions) Balance at December 31, 2022 $ (5,800) Amortization 240 Additions (1) (567) Balance at June 30, 2023 $ (6,127)

EQUITY

EQUITY	6 Months Ended
	Jun. 30, 2023
Equity [Abstract]
EQUITY	EQUITY Settlement of Equity Units 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 137 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 purchase contract component of each equity unit and is subject to certain adjustments as provided therein. The common stock to be received by these unitholders was originally valued at approximately $1.3 billion and recognized in shareholders’ equity by PG&E Corporation upon the issuance of the equity units. The stated settlement date of each of the equity units’ purchase contracts is August 16, 2023, subject to acceleration or postponement as provided in such purchase contracts. During the three months ended June 30, 2023, certain unitholders accelerated the settlement date for 8 million PG&E Corporation equity units, resulting in the issuance of 67 million shares of PG&E Corporation common stock, valued at approximately $634 million. Subsequently, through July 19, 2023, certain unitholders accelerated the settlement date for an additional 3 million PG&E Corporation equity units, resulting in the issuance of 28 million shares of PG&E Corporation common stock, valued at approximately $270 million. Based on trading prices as of July 19, 2023, the remaining outstanding equity units are expected to convert into 42 million shares during the third quarter of 2023, subject to change based on trading prices for the final measurement period. Ownership Restrictions in PG&E Corporation’s Amended Articles Under Section 382 of the IRC, 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 deferred tax assets 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 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 2,568,984,928 shares outstanding as of July 19, 2023, only 2,023,497,748 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 taking into account the shares of PG&E Corporation common stock known to have been sold by the Fire Victim Trust as of July 19, 2023, a person’s effective Percentage Stock Ownership limitation for purposes of the Amended Articles as of July 19, 2023 was 3.74% of the outstanding shares. At various dates throughout 2022 and during the six months ended June 30, 2023, the Fire Victim Trust exchanged Plan Shares for an equal number of New Shares in the manner contemplated by the Share Exchange and Tax Matters Agreement; in each case, the Fire Victim Trust thereafter reported that it sold the applicable New Shares. During the six months ended June 30, 2023, the Fire Victim Trust’s sale of PG&E Corporation common stock in the aggregate amount of 120,000,000 shares resulted in an aggregate tax benefit of $527 million recorded in PG&E Corporation’s and the Utility’s Condensed Consolidated Financial Statements. Cumulatively through June 30, 2023, the Fire Victim Trust has sold 350,000,000 shares resulting in an aggregate tax benefit of approximately $1.4 billion recorded in PG&E Corporation’s and the Utility’s Condensed Consolidated Financial Statements. Subsequently, on July 12, 2023, the Fire Victim Trust exchanged an additional 60,000,000 Plan Shares for an equal number of New Shares in the manner contemplated by the Share Exchange and Tax Matters Agreement; the Fire Victim Trust thereafter reported that it sold the applicable New Shares. As of July 19, 2023, to the knowledge of PG&E Corporation, the Fire Victim Trust had sold 410,000,000 shares of PG&E Corporation common stock in the aggregate and owned 67,743,590 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 IRC. Dividends On December 15, 2022, the Board of Directors of the Utility declared dividends on its outstanding series of preferred stock totaling $3.5 million, which was paid on February 15, 2023, to holders of record on January 31, 2023. On February 16, 2023, the Board of Directors of the Utility declared dividends on its outstanding series of preferred stock totaling $3.5 million, which was paid on May 15, 2023, to holders of record on April 28, 2023. On May 18, 2023, the Board of Directors of the Utility declared dividends on its outstanding series of preferred stock totaling $3.5 million, payable on August 15, 2023, to holders of record on July 31, 2023. On February 16, 2023, the Board of Directors of the Utility declared a common stock dividend of $425 million, which was paid to PG&E Corporation on February 28, 2023. On May 18, 2023, the Board of Directors of the Utility declared a common stock dividend of $450 million, which was paid to PG&E Corporation on June 21, 2023. On December 20, 2017, the Boards of Directors of PG&E Corporation suspended quarterly cash dividends on PG&E Corporation common stock, beginning the fourth quarter of 2017. 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. Pursuant to the Confirmation Order, PG&E Corporation may not pay dividends on shares of its common stock until it recognizes $6.2 billion in Non-GAAP Core Earnings following the Emergence Date. “Non-GAAP Core Earnings” means GAAP earnings adjusted for certain non-core items as described in the Plan. PG&E Corporation is unable to predict when it will commence the payment of dividends on its common stock.

EARNINGS PER SHARE

EARNINGS PER SHARE	6 Months Ended
	Jun. 30, 2023
Earnings Per Share [Abstract]
EARNINGS PER SHARE	EARNINGS PER SHARE PG&E Corporation’s basic EPS is calculated by dividing the income 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 available for common shareholders and weighted average common shares outstanding for calculating diluted EPS: Three Months Ended June 30, Six Months Ended June 30, (in millions, except per share amounts) 2023 2022 2023 2022 Income available for common shareholders $ 406 $ 356 $ 975 $ 831 Weighted average common shares outstanding, basic 2,019 1,987 2,005 1,987 Add incremental shares from assumed conversions: Employee share-based compensation 6 8 6 8 Equity Units 114 146 126 146 Weighted average common shares outstanding, diluted 2,139 2,141 2,137 2,141 Total income per common share, diluted $ 0.19 $ 0.17 $ 0.46 $ 0.39 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.

DERIVATIVES

DERIVATIVES	6 Months Ended
	Jun. 30, 2023
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 Condensed 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 Condensed 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 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 Condensed Consolidated Balance Sheets at fair value. Volume of Derivative Activity The volumes of the Utility’s outstanding derivatives were as follows: Contract Volume at Underlying Product Instruments June 30, 2023 December 31, 2022 Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 246,078,190 171,212,813 Options 44,745,000 27,785,000 Electricity (MWh) Forwards, Futures and Swaps 9,389,471 10,814,728 Options 277,200 215,600 Congestion Revenue Rights (3) 180,123,433 205,743,505 (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 As of June 30, 2023, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 147 $ (11) $ 31 $ 167 Other noncurrent assets – other 239 — — 239 Current liabilities – other (80) 11 16 (53) Noncurrent liabilities – other (164) — 1 (163) Total commodity risk $ 142 $ — $ 48 $ 190 As of December 31, 2022, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 824 $ (170) $ 537 $ 1,191 Other noncurrent assets – other 306 — — 306 Current liabilities – other (238) 170 16 (52) Noncurrent liabilities – other (177) — — (177) Total commodity risk $ 715 $ — $ 553 $ 1,268 Cash inflows and outflows associated with derivatives are included in operating cash flows on the Utility’s Condensed Consolidated Statements of Cash Flows.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	6 Months Ended
	Jun. 30, 2023
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 June 30, 2023 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 723 $ — $ — $ — $ 723 Nuclear decommissioning trusts Short-term investments 126 — — — 126 Global equity securities 2,035 — — — 2,035 Fixed-income securities 1,195 793 — — 1,988 Assets measured at NAV — — — — 29 Total nuclear decommissioning trusts (2) 3,356 793 — — 4,178 Customer credit trust Short-term investments 7 — — — 7 Global equity securities 148 — — — 148 Fixed-income securities 85 236 — — 321 Total customer credit trust 240 236 — — 476 Price risk management instruments (Note 8) Electricity — 28 330 11 369 Gas — 28 — 9 37 Total price risk management instruments — 56 330 20 406 Rabbi trusts Short-term investments 97 — — — 97 Global equity securities 5 — — — 5 Life insurance contracts — 65 — — 65 Total rabbi trusts 102 65 — — 167 Long-term disability trust Short-term investments 7 — — — 7 Assets measured at NAV — — — — 117 Total long-term disability trust 7 — — — 124 TOTAL ASSETS $ 4,428 $ 1,150 $ 330 $ 20 $ 6,074 Liabilities: Price risk management instruments (Note 8) Electricity $ — $ 31 $ 204 $ (26) $ 209 Gas — 9 — (2) 7 TOTAL LIABILITIES $ — $ 40 $ 204 $ (28) $ 216 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. (2) Represents amount before deducting $654 million primarily related to deferred taxes on appreciation of investment value. Fair Value Measurements December 31, 2022 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 658 $ — $ — $ — $ 658 Fixed-income securities — 49 — — 49 Nuclear decommissioning trusts Short-term investments 117 — — — 117 Global equity securities 1,845 — — — 1,845 Fixed-income securities 1,094 791 — — 1,885 Assets measured at NAV — — — — 25 Total nuclear decommissioning trusts (2) 3,056 791 — — 3,872 Customer credit trust Short-term investments 19 — — — 19 Global equity securities 218 — — — 218 Fixed-income securities 216 292 — — 508 Total customer credit trust 453 292 — — 745 Price risk management instruments (Note 8) Electricity — 94 432 40 566 Gas — 604 — 327 931 Total price risk management instruments — 698 432 367 1,497 Rabbi trusts Short-term investments 25 — — — 25 Global equity securities 5 — — — 5 Fixed-income securities — 69 — — 69 Life insurance contracts — 64 — — 64 Total rabbi trusts 30 133 — — 163 Long-term disability trust Short-term investments 10 — — — 10 Assets measured at NAV — — — — 133 Total long-term disability trust 10 — — — 143 TOTAL ASSETS $ 4,207 $ 1,963 $ 432 $ 367 $ 7,127 Liabilities: Price risk management instruments (Note 8) Electricity $ — $ 10 $ 233 $ (20) $ 223 Gas — 172 — (166) 6 TOTAL LIABILITIES $ — $ 182 $ 233 $ (186) $ 229 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. (2) Represents amount before deducting $575 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 six months ended June 30, 2023 and 2022. 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, customer credit 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 classified as 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 Condensed 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 on net income resulting from changes in the fair value of these instruments. See Note 8 above. Fair Value at (in millions) At June 30, 2023 Valuation Unobservable Fair Value Measurement Assets Liabilities Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 272 $ 121 Market approach CRR auction prices $ (145.09) - 843.59 / 0.92 Power purchase agreements $ 58 $ 83 Discounted cash flow Forward prices $ (7.91) - 263.13 / 64.94 (1) Represents price per MWh. (2) Unobservable inputs were weighted by the relative fair value of the instruments. Fair Value at (in millions) At December 31, 2022 Valuation Unobservable Fair Value Measurement Assets Liabilities Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 305 $ 138 Market approach CRR auction prices $ (145.09) - 2,724.93 / 0.89 Power purchase agreements $ 127 $ 95 Discounted cash flow Forward prices $ (6.39) - 286.75 / 78.14 (1) Represents price per MWh. (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 three and six months ended June 30, 2023 and 2022, respectively: Price Risk Management Instruments (in millions) 2023 2022 Asset (Liability) balance as of April 1 $ 212 $ (24) Net realized and unrealized gains (losses): Included in regulatory assets and liabilities or balancing accounts (1) (86) 35 Asset balance as of June 30 $ 126 $ 11 (1) The costs related to price risk management activities are recovered through rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted. Price Risk Management Instruments (in millions) 2023 2022 Asset (Liability) balance as of January 1 $ 199 $ (34) Net realized and unrealized gains (losses): Included in regulatory assets and liabilities or balancing accounts (1) (73) 45 Asset balance as of June 30 $ 126 $ 11 (1) The costs related to price risk management activities are recovered through 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 as of June 30, 2023 and December 31, 2022, 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 June 30, 2023 At December 31, 2022 (in millions) Carrying Amount Level 2 Fair Value Carrying Amount Level 2 Fair Value Debt (Note 4) PG&E Corporation $ 4,430 $ 4,489 $ 4,355 $ 4,490 Utility 35,625 30,473 32,847 27,666 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 June 30, 2023 Nuclear decommissioning trusts Short-term investments $ 126 $ — $ — $ 126 Global equity securities 391 1,684 (11) 2,064 Fixed-income securities 2,083 14 (109) 1,988 Total (1) $ 2,600 $ 1,698 $ (120) $ 4,178 As of December 31, 2022 Nuclear decommissioning trusts Short-term investments $ 117 $ — $ — $ 117 Global equity securities 413 1,468 (11) 1,870 Fixed-income securities 1,991 10 (116) 1,885 Total (1) $ 2,521 $ 1,478 $ (127) $ 3,872 (1) Represents amounts before deducting $654 million and $575 million as of June 30, 2023 and December 31, 2022, 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) June 30, 2023 Less than 1 year $ 22 1–5 years 627 5–10 years 497 More than 10 years 842 Total maturities of fixed-income securities $ 1,988 The following table provides a summary of activity for the fixed-income and equity securities: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2023 2022 2023 2022 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 474 $ 948 $ 751 $ 1,369 Gross realized gains on securities 37 81 42 137 Gross realized losses on securities (10) (58) (18) (65) Customer Credit Trust The following table provides a summary of equity securities and available-for-sale debt securities: (in millions) Amortized Total Total Total Fair As of June 30, 2023 Customer credit trust Short-term investments $ 7 $ — $ — $ 7 Global equity securities 129 23 (4) 148 Fixed-income securities 323 — (2) 321 Total $ 459 $ 23 $ (6) $ 476 As of December 31, 2022 Customer credit trust Short-term investments $ 19 $ — $ — $ 19 Global equity securities 219 13 (14) 218 Fixed-income securities 516 — (8) 508 Total $ 754 $ 13 $ (22) $ 745 The fair value of fixed-income securities by contractual maturity is as follows: As of (in millions) June 30, 2023 Less than 1 year $ — 1–5 years 88 5–10 years 80 More than 10 years 153 Total maturities of fixed-income securities $ 321 The following table provides a summary of activity for the fixed-income and equity securities: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2023 2022 2023 2022 Proceeds from sales and maturities of customer credit trust investments $ 135 $ — $ 304 $ — Gross realized gains on securities 6 1 8 1 Gross realized losses on securities (1) (5) (8) (10) (8) (1) Includes $4.3 million of impaired debt securities which were written down to their respective fair values during the three and six months ended June 30, 2023.

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES	6 Months Ended
	Jun. 30, 2023
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. Assessing whether a loss is probable or reasonably possible, whether the loss or a range of losses is estimable, and the amount of the best estimate or lower end of the range often requires management to exercise significant judgment about future events. Management makes these assessments based on a number of assumptions and subjective factors, including 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, and estimates based on currently available information and prior experience with wildfires. Loss contingencies are reviewed quarterly, and estimates are adjusted to reflect the impact of all known information. 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. 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. 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. 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 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. 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 area 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. As of July 19, 2023, PG&E Corporation and the Utility are aware of approximately 124 complaints on behalf of at least 2,839 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. The court scheduled trial for November 7, 2022, which it vacated on October 11, 2022. In addition, on January 5, 2022, Cal Fire filed a complaint against the Utility in the coordinated proceeding seeking to recover approximately $90 million for fire suppression and other costs incurred in connection with the 2019 Kincade fire. The Utility filed an answer to Cal Fire’s complaint on February 4, 2022. On July 20, 2022, PG&E Corporation and the Utility filed a motion for summary adjudication on individual plaintiffs’ claims for punitive damages. The court scheduled a hearing on this summary adjudication motion for October 7, 2022, which it vacated on October 6, 2022. On October 11, 2022, the Utility entered into a tolling agreement with the California Governor’s Office of Emergency Services (“Cal OES”), which remains in effect. 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. Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this report, PG&E Corporation and the Utility recorded a liability in the aggregate amount of $1.025 billion as of December 31, 2022 (before available insurance). The aggregate liability remained unchanged as of June 30, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses of $1.025 billion do not include, among other things: (i) any amounts for potential penalties or fines 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, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 650 Accrued Losses — Payments (192) Balance at June 30, 2023 $ 458 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 June 30, 2023, the Utility recorded an insurance receivable for the full amount of $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 area 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 (“Shasta D.A.”) charged 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. 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 June 9, 2022, the Utility entered a plea of not guilty to all of the charges. At the conclusion of the preliminary hearing conducted in January and February 2023, the court dismissed 20 of the 31 counts, including all charges related to the three smaller fires as well as all charges relating to air contamination. On February 24, 2023, the Utility filed a motion to set aside 10 of the remaining 11 counts. On April 14, 2023, the court issued a written tentative ruling dismissing nine of the remaining counts and inviting the parties to submit additional briefing on the issues discussed in the tentative ruling. On May 31, 2023, the Utility and the Shasta D.A. filed a civil stipulated judgment (the “Zogg Stipulation”) for the Shasta D.A. to dismiss with prejudice all criminal charges against the Utility in connection with the 2020 Zogg fire. On May 31, 2023, the Shasta County Superior Court granted the Shasta D.A.’s motion to dismiss the pending criminal charges. Subject to the terms and conditions of the Zogg Stipulation, the Utility agreed to (1) pay a total of $50 million, which will not be recoverable through rates; (2) take certain wildfire mitigation actions consistent with its then-applicable wildfire mitigation plan and (3) extend the term of the independent compliance monitor to monitor the Utility’s compliance with certain commitments in Shasta County by approximately one year. After the Zogg Stipulation was entered by the Shasta County Superior Court, the Shasta D.A. moved to dismiss the charges with prejudice, which was granted by the court on June 14, 2023. As of June 30, 2023, PG&E Corporation’s and the Utility’s Condensed Consolidated Financial Statements reflected $50 million within Other current liabilities in connection with the Zogg Stipulation. On October 25, 2022, the SED issued a proposed administrative enforcement order alleging that the Utility violated CPUC regulations and Public Utilities Code Section 451 in connection with the CPUC’s investigation of the 2020 Zogg fire. The proposed order recommends a penalty of $155 million. On February 21, 2023, the Utility and the SED filed a joint motion for approval of a settlement agreement (the “Zogg SED Settlement”). The Zogg SED Settlement provides that the Utility would (i) pay $10 million to California’s General Fund; (ii) implement certain enhancements to its vegetation management processes; (iii) incur $140 million in connection with certain initiatives specified in the Zogg SED Settlement, and the Utility may not seek recovery of this $140 million of costs. The SED agreed to refrain from instituting any further enforcement proceedings against the Utility related to the 2020 Zogg fire. The Zogg SED Settlement states that it does not constitute an admission or evidence of any wrongdoing, fault, omission, negligence, imprudence, or liability on the part of the Utility. In connection with the Zogg SED Settlement, PG&E Corporation and the Utility recorded a liability of $10 million reflected in Other current liabilities on the Consolidated Financial Statements for the year ended December 31, 2022. For the $140 million of costs for which the Utility will not seek recovery, the Utility expects to record disallowances as such costs are incurred. On May 24, 2023, the CPUC issued a resolution granting the joint motion filed by the Utility and the SED and approving the Zogg SED Settlement. As of July 19, 2023, PG&E Corporation and the Utility are aware of approximately 29 complaints on behalf of at least 523 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. The court has set a trial date in the coordinated proceeding for September 5, 2023. In addition, on March 18, 2022, Cal Fire filed a complaint against the Utility in the coordinated proceeding seeking to recover approximately $34.5 million for fire suppression and other costs incurred in connection with the 2020 Zogg fire. The Utility filed an answer to Cal Fire’s complaint on May 3, 2022. The Utility and Cal Fire reached a settlement of Cal Fire’s claims and dismissal of Cal Fire’s complaint with prejudice was entered on December 22, 2022. On September 26, 2022, the Utility entered into a tolling agreement with Cal OES, which remains in effect. 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. Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this report, PG&E Corporation and the Utility recorded a liability in the aggregate amount of $400 million as of December 31, 2022 (before available insurance). The aggregate liability remained unchanged as of June 30, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses do not include, among other things: (i) any amounts for potential penalties or fines 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, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 32 Accrued Losses — Payments (13) Balance at June 30, 2023 $ 19 The Utility has liability insurance for third-party liability attributable to the 2020 Zogg fire in an aggregate amount of $611 million. As of June 30, 2023, the Utility recorded an insurance receivable for $372 million for probable insurance recoveries in connection with the 2020 Zogg fire, which equals the $400 million probable loss estimate less an initial self-insured retention of $60 million, plus $32 million in legal fees incurred. Recovery under the Utility’s wildfire insurance policies for the 2021 Dixie fire will reduce the amount of insurance proceeds available for the 2020 Zogg fire by the same amount up to $600 million and vice versa. 2021 Dixie Fire According to the Cal Fire Investigation Report on the 2021 Dixie fire (the “Cal Fire Investigation Report”), on July 13, 2021, at approximately 5:07 p.m. Pacific Time, a wildfire began in the Feather River Canyon near Cresta Dam (the “2021 Dixie fire”), located in the service area of the Utility. According to the Cal Fire Investigation Report, the 2021 Dixie fire consumed 963,309 acres and resulted in 1,311 structures destroyed and 94 structures damaged (including 763 residential homes, 12 multi-family homes, 8 commercial residential homes, 148 nonresidential commercial structures, and 466 detached structures), and four first-responder injuries. The Cal Fire Investigation Report does not attribute a fatality that was previously published in an October 25, 2021 Cal Fire incident report to 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. On June 7, 2022, the Utility received a copy of the Cal Fire Investigation Report, which states that the fire ignited when a tree fell and contacted electrical distribution lines owned and operated by the Utility, and the Cal Fire Investigation Report has been made publicly available. The Cal Fire Investigation Report alleges that the Utility acted negligently in its response to the initial outage and fault that caused the 2021 Dixie fire. The Cal Fire Investigation Report also alleges that the subject tree had visible outward signs of damage and decay which would have been noticeable at the ground level, and that a brief visual inspection should have discovered the decay. Based on the information currently available to the Utility, including its inspection records, operating and inspection protocols and procedures, implementation of those protocols and procedures, and day-of-event response, the Utility believes its personnel acted reasonably (within the meaning of the applicable prudency standard discussed under “Regulatory Recovery” below) given the information available at the time and followed applicable policies and protocols both before ignition and in the day-of-event response. While an intervenor in a future cost recovery proceeding may argue the Cal Fire Investigation Report itself creates serious doubt with respect to the reasonableness of the Utility’s conduct, PG&E Corporation and the Utility do not believe the report identifies sufficient facts to shift the burden of proof applicable in a proceeding for cost recovery to the Utility. (See “Regulatory Recovery” and “Wildfire Fund under AB 1054”). PG&E Corporation and the Utility disagree with many allegations in the Cal Fire Investigation Report and plan to vigorously contest them. However, if the CPUC or the FERC were to reach conclusions similar to those of the Cal Fire Investigation Report, it may determine that the Utility had been imprudent, in which case some or all of its costs recorded to the WEMA would not be recoverable, the Utility would not be able to recover costs through FERC TO rates, or the Utility would be required to reimburse the Wildfire Fund for the costs and expenses that are allocated to it. The SED and OEIS have been 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 also issued a subpoena for documents. PG&E Corporation and the Utility are cooperating with the investigations. Except for the investigation by the District Attorneys of Butte County, Plumas County, Shasta County, Lassen County and Tehama County, whose potential state criminal prosecution of the Utility is resolved, it is uncertain when any other 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. On January 17, 2023, PG&E Corporation and the Utility reached an agreement with certain public entities to settle their claims for $24 million. As of July 19, 2023, PG&E Corporation and the Utility are aware of approximately 143 complaints on behalf of at least 6,380 individual plaintiffs and a separate putative class complaint related to the 2021 Dixie fire and expect that they may receive further complaints. The plaintiffs seek damages that include wrongful death, property damage, economic loss, medical monitoring, punitive damages, exemplary damages, attorneys’ fees and other damages. A trial on individual claims is scheduled to commence on November 8, 2023. Cal Fire also filed a complaint largely repeating the allegations of the earlier Cal Fire Investigation Report and seeking damages for fire suppression and investigation costs. On March 2, 2023, PG&E Corporation and the Utility entered into an agreement with the insurance subrogation plaintiffs in the 2021 Dixie fire litigation to resolve their claims arising from the 2021 Dixie 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 2021 Dixie fire. Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this report, PG&E Corporation and the Utility recorded a liability in the aggregate amount of $1.175 billion as of December 31, 2022 (before available recoveries). The aggregate liability remained unchanged as of June 30, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses of $1.175 billion do not include, among other things: (i) any amounts for potential penalties or fines 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, (v) medical monitoring costs, or (vi) 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. PG&E Corporation and the Utility are 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 Cal Fire Investigation Report, over $650 million of costs had been incurred in suppressing the 2021 Dixie fire. The Utility estimates that the fire burned approximately 70,000 acres of national parks and approximately 685,000 acres of national forests. 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 2021 Dixie fire since December 31, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 1,131 Accrued Losses — Payments (447) Balance at June 30, 2023 $ 684 The Utility has liability insurance coverage for third-party liability in an aggregate amount of $900 million. Recovery under the Utility’s wildfire insurance policies for the 2020 Zogg fire will reduce the amount of insurance proceeds available for the 2021 Dixie fire by the same amount up to $600 million and vice versa. As of June 30, 2023, the Utility recorded an insurance receivable of $528 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 $372 million insurance receivable recorded in connection with the 2020 Zogg fire. As of June 30, 2023, the Utility recorded a Wildfire Fund receivable of $175 million for probable recoveries in connection with the 2021 Dixie fire. AB 1054 provides that the CPUC may allocate costs and expenses in the application for cost recovery in full or in part taking into account factors both within and beyond the utility’s control that may have exacerbated the costs and expenses, including humidity, temperature, and winds. PG&E Corporation and the Utility believe that, even if it found that the Utility acted unreasonably, the CPUC would nevertheless authorize recovery in part. See “Wildfire Fund under AB 1054” below. The Utility also recorded a $117 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 $411 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. The WEMA regulatory asset increased by $23 million during the six months ended June 30, 2023. 2022 Mosquito Fire On September 6, 2022, at approximately 6:17 p.m. Pacific Time, the Utility was notified that a wildfire had ignited near OxBow Reservoir in Placer County, California (the “2022 Mosquito fire”), located in the service area of the Utility. The National Wildfire Coordinating Group’s InciWeb incident overview dated November 4, 2022 at 6:30 p.m. Pacific Time indicated that the 2022 Mosquito fire had consumed approximately 76,788 acres at that time. It also indicated no fatalities, no injuries, 78 structures destroyed, and 13 structures damaged (including 44 residential homes and 40 detached structures) and that the fire was 100% contained. The USFS has indicated to the Utility an initial assessment that the fire started in the area of the Utility’s power line on National Forest System lands and that the USFS is conducting a criminal investigation into the 2022 Mosquito fire. On September 24, 2022, the USFS removed and took possession of one of the Utility’s transmission poles and attached equipment. The USFS has not issued a determination as to the cause. The cause of the 2022 Mosquito fire remains under investigation by the USFS and the DOJ, and PG&E Corporation and the Utility are cooperating with the investigation. PG&E Corporation and the Utility have received document and information requests from the DOJ. 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 2022 Mosquito fire. This investigation is preliminary, and PG&E Corporation and the Utility do not currently have access to the evidence in the possession of the USFS, the DOJ, or other third parties. The CPUC and other entities may also be investigating the 2022 Mosquito fire. It is uncertain when any such investigations will be complete. As of July 19, 2023, PG&E Corporation and the Utility are aware of approximately six complaints on behalf of at least 236 individual plaintiffs related to the 2022 Mosquito fire and expect that they may receive further complaints. PG&E Corporation and the Utility also are aware of a complaint on behalf of the Placer County Water Agency, a complaint on behalf of the Middle Fork Project Finance Authority, a complaint on behalf of El Dorado County, Placer County, Georgetown Divide Public Utility District, Georgetown Fire Protection District, and El Dorado County Water Agency, and three complaints on behalf of the subrogation insurers. 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 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 2022 Mosquito fire. Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this report, PG&E Corporation and the Utility recorded a liability in the aggregate amount of $100 million as of December 31, 2022 (before available insurance). The aggregate liability remained unchanged as of June 30, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses do not include, among other things: (i) any amounts for potential penalties or fines 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. The Utility’s accrued estimated losses also do not include any assumptions regarding offsetting recoveries from third-parties (outside of the Utility’s insurers). As noted above, the aggregate estimated liability for claims in connection with the 2022 Mosquito 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 Corporatio

OTHER CONTINGENCIES AND COMMITM

OTHER CONTINGENCIES AND COMMITMENTS	6 Months Ended
	Jun. 30, 2023
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. Assessing whether a loss is probable or reasonably possible, whether the loss or a range of losses is estimable, and the amount of the best estimate or lower end of the range often requires management to exercise significant judgment about future events. Management makes these assessments based on a number of assumptions and subjective factors, including 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, and estimates based on currently available information and prior experience with wildfires. Loss contingencies are reviewed quarterly, and estimates are adjusted to reflect the impact of all known information. 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. 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. 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. 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 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. 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 area 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. As of July 19, 2023, PG&E Corporation and the Utility are aware of approximately 124 complaints on behalf of at least 2,839 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. The court scheduled trial for November 7, 2022, which it vacated on October 11, 2022. In addition, on January 5, 2022, Cal Fire filed a complaint against the Utility in the coordinated proceeding seeking to recover approximately $90 million for fire suppression and other costs incurred in connection with the 2019 Kincade fire. The Utility filed an answer to Cal Fire’s complaint on February 4, 2022. On July 20, 2022, PG&E Corporation and the Utility filed a motion for summary adjudication on individual plaintiffs’ claims for punitive damages. The court scheduled a hearing on this summary adjudication motion for October 7, 2022, which it vacated on October 6, 2022. On October 11, 2022, the Utility entered into a tolling agreement with the California Governor’s Office of Emergency Services (“Cal OES”), which remains in effect. 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. Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this report, PG&E Corporation and the Utility recorded a liability in the aggregate amount of $1.025 billion as of December 31, 2022 (before available insurance). The aggregate liability remained unchanged as of June 30, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses of $1.025 billion do not include, among other things: (i) any amounts for potential penalties or fines 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, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 650 Accrued Losses — Payments (192) Balance at June 30, 2023 $ 458 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 June 30, 2023, the Utility recorded an insurance receivable for the full amount of $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 area 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 (“Shasta D.A.”) charged 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. 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 June 9, 2022, the Utility entered a plea of not guilty to all of the charges. At the conclusion of the preliminary hearing conducted in January and February 2023, the court dismissed 20 of the 31 counts, including all charges related to the three smaller fires as well as all charges relating to air contamination. On February 24, 2023, the Utility filed a motion to set aside 10 of the remaining 11 counts. On April 14, 2023, the court issued a written tentative ruling dismissing nine of the remaining counts and inviting the parties to submit additional briefing on the issues discussed in the tentative ruling. On May 31, 2023, the Utility and the Shasta D.A. filed a civil stipulated judgment (the “Zogg Stipulation”) for the Shasta D.A. to dismiss with prejudice all criminal charges against the Utility in connection with the 2020 Zogg fire. On May 31, 2023, the Shasta County Superior Court granted the Shasta D.A.’s motion to dismiss the pending criminal charges. Subject to the terms and conditions of the Zogg Stipulation, the Utility agreed to (1) pay a total of $50 million, which will not be recoverable through rates; (2) take certain wildfire mitigation actions consistent with its then-applicable wildfire mitigation plan and (3) extend the term of the independent compliance monitor to monitor the Utility’s compliance with certain commitments in Shasta County by approximately one year. After the Zogg Stipulation was entered by the Shasta County Superior Court, the Shasta D.A. moved to dismiss the charges with prejudice, which was granted by the court on June 14, 2023. As of June 30, 2023, PG&E Corporation’s and the Utility’s Condensed Consolidated Financial Statements reflected $50 million within Other current liabilities in connection with the Zogg Stipulation. On October 25, 2022, the SED issued a proposed administrative enforcement order alleging that the Utility violated CPUC regulations and Public Utilities Code Section 451 in connection with the CPUC’s investigation of the 2020 Zogg fire. The proposed order recommends a penalty of $155 million. On February 21, 2023, the Utility and the SED filed a joint motion for approval of a settlement agreement (the “Zogg SED Settlement”). The Zogg SED Settlement provides that the Utility would (i) pay $10 million to California’s General Fund; (ii) implement certain enhancements to its vegetation management processes; (iii) incur $140 million in connection with certain initiatives specified in the Zogg SED Settlement, and the Utility may not seek recovery of this $140 million of costs. The SED agreed to refrain from instituting any further enforcement proceedings against the Utility related to the 2020 Zogg fire. The Zogg SED Settlement states that it does not constitute an admission or evidence of any wrongdoing, fault, omission, negligence, imprudence, or liability on the part of the Utility. In connection with the Zogg SED Settlement, PG&E Corporation and the Utility recorded a liability of $10 million reflected in Other current liabilities on the Consolidated Financial Statements for the year ended December 31, 2022. For the $140 million of costs for which the Utility will not seek recovery, the Utility expects to record disallowances as such costs are incurred. On May 24, 2023, the CPUC issued a resolution granting the joint motion filed by the Utility and the SED and approving the Zogg SED Settlement. As of July 19, 2023, PG&E Corporation and the Utility are aware of approximately 29 complaints on behalf of at least 523 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. The court has set a trial date in the coordinated proceeding for September 5, 2023. In addition, on March 18, 2022, Cal Fire filed a complaint against the Utility in the coordinated proceeding seeking to recover approximately $34.5 million for fire suppression and other costs incurred in connection with the 2020 Zogg fire. The Utility filed an answer to Cal Fire’s complaint on May 3, 2022. The Utility and Cal Fire reached a settlement of Cal Fire’s claims and dismissal of Cal Fire’s complaint with prejudice was entered on December 22, 2022. On September 26, 2022, the Utility entered into a tolling agreement with Cal OES, which remains in effect. 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. Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this report, PG&E Corporation and the Utility recorded a liability in the aggregate amount of $400 million as of December 31, 2022 (before available insurance). The aggregate liability remained unchanged as of June 30, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses do not include, among other things: (i) any amounts for potential penalties or fines 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, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 32 Accrued Losses — Payments (13) Balance at June 30, 2023 $ 19 The Utility has liability insurance for third-party liability attributable to the 2020 Zogg fire in an aggregate amount of $611 million. As of June 30, 2023, the Utility recorded an insurance receivable for $372 million for probable insurance recoveries in connection with the 2020 Zogg fire, which equals the $400 million probable loss estimate less an initial self-insured retention of $60 million, plus $32 million in legal fees incurred. Recovery under the Utility’s wildfire insurance policies for the 2021 Dixie fire will reduce the amount of insurance proceeds available for the 2020 Zogg fire by the same amount up to $600 million and vice versa. 2021 Dixie Fire According to the Cal Fire Investigation Report on the 2021 Dixie fire (the “Cal Fire Investigation Report”), on July 13, 2021, at approximately 5:07 p.m. Pacific Time, a wildfire began in the Feather River Canyon near Cresta Dam (the “2021 Dixie fire”), located in the service area of the Utility. According to the Cal Fire Investigation Report, the 2021 Dixie fire consumed 963,309 acres and resulted in 1,311 structures destroyed and 94 structures damaged (including 763 residential homes, 12 multi-family homes, 8 commercial residential homes, 148 nonresidential commercial structures, and 466 detached structures), and four first-responder injuries. The Cal Fire Investigation Report does not attribute a fatality that was previously published in an October 25, 2021 Cal Fire incident report to 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. On June 7, 2022, the Utility received a copy of the Cal Fire Investigation Report, which states that the fire ignited when a tree fell and contacted electrical distribution lines owned and operated by the Utility, and the Cal Fire Investigation Report has been made publicly available. The Cal Fire Investigation Report alleges that the Utility acted negligently in its response to the initial outage and fault that caused the 2021 Dixie fire. The Cal Fire Investigation Report also alleges that the subject tree had visible outward signs of damage and decay which would have been noticeable at the ground level, and that a brief visual inspection should have discovered the decay. Based on the information currently available to the Utility, including its inspection records, operating and inspection protocols and procedures, implementation of those protocols and procedures, and day-of-event response, the Utility believes its personnel acted reasonably (within the meaning of the applicable prudency standard discussed under “Regulatory Recovery” below) given the information available at the time and followed applicable policies and protocols both before ignition and in the day-of-event response. While an intervenor in a future cost recovery proceeding may argue the Cal Fire Investigation Report itself creates serious doubt with respect to the reasonableness of the Utility’s conduct, PG&E Corporation and the Utility do not believe the report identifies sufficient facts to shift the burden of proof applicable in a proceeding for cost recovery to the Utility. (See “Regulatory Recovery” and “Wildfire Fund under AB 1054”). PG&E Corporation and the Utility disagree with many allegations in the Cal Fire Investigation Report and plan to vigorously contest them. However, if the CPUC or the FERC were to reach conclusions similar to those of the Cal Fire Investigation Report, it may determine that the Utility had been imprudent, in which case some or all of its costs recorded to the WEMA would not be recoverable, the Utility would not be able to recover costs through FERC TO rates, or the Utility would be required to reimburse the Wildfire Fund for the costs and expenses that are allocated to it. The SED and OEIS have been 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 also issued a subpoena for documents. PG&E Corporation and the Utility are cooperating with the investigations. Except for the investigation by the District Attorneys of Butte County, Plumas County, Shasta County, Lassen County and Tehama County, whose potential state criminal prosecution of the Utility is resolved, it is uncertain when any other 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. On January 17, 2023, PG&E Corporation and the Utility reached an agreement with certain public entities to settle their claims for $24 million. As of July 19, 2023, PG&E Corporation and the Utility are aware of approximately 143 complaints on behalf of at least 6,380 individual plaintiffs and a separate putative class complaint related to the 2021 Dixie fire and expect that they may receive further complaints. The plaintiffs seek damages that include wrongful death, property damage, economic loss, medical monitoring, punitive damages, exemplary damages, attorneys’ fees and other damages. A trial on individual claims is scheduled to commence on November 8, 2023. Cal Fire also filed a complaint largely repeating the allegations of the earlier Cal Fire Investigation Report and seeking damages for fire suppression and investigation costs. On March 2, 2023, PG&E Corporation and the Utility entered into an agreement with the insurance subrogation plaintiffs in the 2021 Dixie fire litigation to resolve their claims arising from the 2021 Dixie 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 2021 Dixie fire. Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this report, PG&E Corporation and the Utility recorded a liability in the aggregate amount of $1.175 billion as of December 31, 2022 (before available recoveries). The aggregate liability remained unchanged as of June 30, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses of $1.175 billion do not include, among other things: (i) any amounts for potential penalties or fines 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, (v) medical monitoring costs, or (vi) 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. PG&E Corporation and the Utility are 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 Cal Fire Investigation Report, over $650 million of costs had been incurred in suppressing the 2021 Dixie fire. The Utility estimates that the fire burned approximately 70,000 acres of national parks and approximately 685,000 acres of national forests. 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 2021 Dixie fire since December 31, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 1,131 Accrued Losses — Payments (447) Balance at June 30, 2023 $ 684 The Utility has liability insurance coverage for third-party liability in an aggregate amount of $900 million. Recovery under the Utility’s wildfire insurance policies for the 2020 Zogg fire will reduce the amount of insurance proceeds available for the 2021 Dixie fire by the same amount up to $600 million and vice versa. As of June 30, 2023, the Utility recorded an insurance receivable of $528 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 $372 million insurance receivable recorded in connection with the 2020 Zogg fire. As of June 30, 2023, the Utility recorded a Wildfire Fund receivable of $175 million for probable recoveries in connection with the 2021 Dixie fire. AB 1054 provides that the CPUC may allocate costs and expenses in the application for cost recovery in full or in part taking into account factors both within and beyond the utility’s control that may have exacerbated the costs and expenses, including humidity, temperature, and winds. PG&E Corporation and the Utility believe that, even if it found that the Utility acted unreasonably, the CPUC would nevertheless authorize recovery in part. See “Wildfire Fund under AB 1054” below. The Utility also recorded a $117 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 $411 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. The WEMA regulatory asset increased by $23 million during the six months ended June 30, 2023. 2022 Mosquito Fire On September 6, 2022, at approximately 6:17 p.m. Pacific Time, the Utility was notified that a wildfire had ignited near OxBow Reservoir in Placer County, California (the “2022 Mosquito fire”), located in the service area of the Utility. The National Wildfire Coordinating Group’s InciWeb incident overview dated November 4, 2022 at 6:30 p.m. Pacific Time indicated that the 2022 Mosquito fire had consumed approximately 76,788 acres at that time. It also indicated no fatalities, no injuries, 78 structures destroyed, and 13 structures damaged (including 44 residential homes and 40 detached structures) and that the fire was 100% contained. The USFS has indicated to the Utility an initial assessment that the fire started in the area of the Utility’s power line on National Forest System lands and that the USFS is conducting a criminal investigation into the 2022 Mosquito fire. On September 24, 2022, the USFS removed and took possession of one of the Utility’s transmission poles and attached equipment. The USFS has not issued a determination as to the cause. The cause of the 2022 Mosquito fire remains under investigation by the USFS and the DOJ, and PG&E Corporation and the Utility are cooperating with the investigation. PG&E Corporation and the Utility have received document and information requests from the DOJ. 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 2022 Mosquito fire. This investigation is preliminary, and PG&E Corporation and the Utility do not currently have access to the evidence in the possession of the USFS, the DOJ, or other third parties. The CPUC and other entities may also be investigating the 2022 Mosquito fire. It is uncertain when any such investigations will be complete. As of July 19, 2023, PG&E Corporation and the Utility are aware of approximately six complaints on behalf of at least 236 individual plaintiffs related to the 2022 Mosquito fire and expect that they may receive further complaints. PG&E Corporation and the Utility also are aware of a complaint on behalf of the Placer County Water Agency, a complaint on behalf of the Middle Fork Project Finance Authority, a complaint on behalf of El Dorado County, Placer County, Georgetown Divide Public Utility District, Georgetown Fire Protection District, and El Dorado County Water Agency, and three complaints on behalf of the subrogation insurers. 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 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 2022 Mosquito fire. Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this report, PG&E Corporation and the Utility recorded a liability in the aggregate amount of $100 million as of December 31, 2022 (before available insurance). The aggregate liability remained unchanged as of June 30, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses do not include, among other things: (i) any amounts for potential penalties or fines 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. The Utility’s accrued estimated losses also do not include any assumptions regarding offsetting recoveries from third-parties (outside of the Utility’s insurers). As noted above, the aggregate estimated liability for claims in connection with the 2022 Mosquito 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 Corporatio

Insider Trading Arrangements

Insider Trading Arrangements - Cheryl F. Campbell [Member]	3 Months Ended	6 Months Ended
	Jun. 30, 2023 shares	Jun. 30, 2023 shares
Trading Arrangements, by Individual
Material Terms of Trading Arrangement		On June 7, 2023, Cheryl F. Campbell, who serves as a non-employee director on each of PG&E Corporation’s and the Utility’s Boards of Directors and is Chair of the Utility’s Board of Directors, adopted a Rule 10b5-1 trading arrangement that is intended to satisfy the affirmative defense of Rule 10b5-1(c), for the sale of up to 10,000 shares of PG&E Corporation common stock. The trading arrangement will terminate on the earlier of March 15, 2024 or the execution of the sale of all 10,000 shares. Certain officers have made elections to participate in, and are participating in, the PG&E Corporation Retirement Savings Plan (the 401(k) plan), which includes a PG&E Corporation Common Stock Fund investment option, and non-qualified deferred compensation plans, which may have a similar option and are described in PG&E Corporation’s and the Utility’s joint proxy statement. Also, certain officers have made, and may from time to time make, elections to have shares withheld to cover withholding taxes upon the vesting of restricted stock units or performance share units, or to pay the exercise price and withholding taxes for stock options, which may be designed to satisfy the affirmative defense conditions of Rule 10b5-1 under the Exchange Act or may constitute non-Rule 10b5-1 trading arrangements (as defined in Item 408(c) of Regulation S-K).
Name	Cheryl F. Campbell
Title	non-employee director
Rule 10b5-1 Arrangement Adopted	true
Adoption Date	June 7, 2023
Arrangement Duration	282 days
Aggregate Available	10,000	10,000

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	6 Months Ended
	Jun. 30, 2023
Accounting Policies [Abstract]
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 Condensed 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. CPUC and FERC rates decouple authorized revenue from the volume of electricity and natural gas sales, so the Utility receives revenue equal to the amounts authorized by the relevant regulatory agencies. As a result, the volume of electricity and natural gas sold does not have a direct impact on PG&E Corporation’s and the Utility’s financial results. 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.
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 June 30, 2023, PG&E Corporation and the Utility 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. During the three and six months ended June 30, 2023, expected credit losses of $154 million and $293 million, respectively, were recorded in Operating and maintenance expense on the Condensed Consolidated Statements of Income for credit losses associated with trade and other receivables. For the three and six months ended June 30, 2022, expected credit losses were $33 million and $76 million, respectively. The portion of expected credit losses that are deemed probable of recovery are deferred to the RUBA, CPPMA, and a FERC regulatory asset. As of June 30, 2023, the RUBA current balancing accounts receivable balance was $228 million, and CPPMA and FERC long-term regulatory asset balances were $4 million and $42 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 10 below. Wildfire Fund receivables risk is related to the Wildfire Fund’s durability, which is a measurement of its 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 their available-for-sale debt securities (i.e., impairment). If such an impairment exists and does not otherwise result in a write-down, then PG&E Corporation and the Utility must determine whether a portion of the impairment is a result of expected credit loss.
Government Assistance	PG&E Corporation and the Utility received various government assistance programs during the six months ended June 30, 2023. PG&E Corporation’s and the Utility’s accounting policy is to apply a grant accounting model by analogy to International Accounting Standards 20, Accounting for Government Grants and Disclosure of Government Assistance . Assembly Bill 180 On June 30, 2022, AB 180 became law. AB 180 authorized the DWR to use up to $75 million to support contracts with the owners of electric generating facilities pending retirement, such as Diablo Canyon, to fund, reimburse or compensate the owner for any costs, expenses or financial commitments incurred to retain the future availability of such generating facilities pending further legislation. The resulting agreement between DWR and the Utility was effective beginning October 1, 2022, and will continue until full disbursement of funds or termination per the agreement. In the event of a termination, the Utility will take reasonable steps to end activities associated with this agreement and will return to DWR any unused funds. The Utility plans to record the income related to government grants as a deduction to Operating and maintenance expense as eligible costs are incurred. DWR Loan Agreement On October 18, 2022, the DWR and the Utility executed a $1.4 billion loan agreement to support the extension of Diablo Canyon, up to approximately $1.1 billion of which could be repaid by funds received from the DOE (see “U.S. DOE’s Civil Nuclear Credit Program” below). Under the loan agreement, the DWR pays the Utility a monthly performance-based disbursement equal to $7 for each MWh generated by Diablo Canyon, effective September 2, 2022. The Utility may use the proceeds of the performance-based disbursements for any business purpose, except as profits or dividends to shareholders or as otherwise prohibited by SB 846. The Utility began earning performance-based disbursements beginning on September 2, 2022 and is eligible to earn performance-based disbursements until the previously-approved retirement dates for Diablo Canyon Unit 1 and Unit 2 (2024 and 2025, respectively). The performance-based disbursements are contingent upon the Utility’s ongoing efforts to pursue extension of and continued safe and reliable operation of Diablo Canyon. The aggregate amount of performance-based disbursements under this agreement will not exceed $300 million. The Utility initially accounts for all disbursements from the DWR loan agreement pursuant to ASC 470, Debt. When there is reasonable assurance that the Utility will have loan disbursements forgiven by the DWR, such as when the Utility earns a performance-based disbursement, the Utility will recognize those forgiven loans as income related to government grants. The Utility plans to record the income related to government grants as a deduction to Operating and maintenance expense in the same period(s) that eligible costs are incurred. As of June 30, 2023, the Condensed Consolidated Financial Statements reflected $245 million in Long-term debt, $15 million in Other current liabilities for income related to eligible costs not yet incurred, and a deduction of $52 million to Operating and maintenance expense for income related to government grants for performance-based disbursements. U.S. DOE’s Civil Nuclear Credit Program On November 17, 2022, the Utility was conditionally awarded a total of approximately $1.1 billion from the DOE related to Diablo Canyon (See “DWR Loan Agreement” above). Final award amounts will be determined following completion of each year of the award period, and amounts awarded over a four-year award period ending in 2026 will be based on actual costs. The Utility will repay its loans outstanding under the DWR Loan Agreement with funding received from the DOE’s Civil Nuclear Credit Program. When there is reasonable assurance that the Utility will receive funding and comply with the conditions of the DOE’s Civil Nuclear Credit Program, the Utility will recognize such funding as income related to government grants. During the three and six months ended June 30, 2023, the Condensed Consolidated Statements of Income reflected $34 million as a deduction to Operating and maintenance expense
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 was created in connection with the Receivables Securitization Program and 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”). The pledged receivables and the corresponding debt are included in Accounts receivable, Accrued unbilled revenue, Other noncurrent assets, and Long-term debt on the Condensed Consolidated Balance Sheets. 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 six months ended June 30, 2023 or is expected to be provided in the future that was not previously contractually required. As of June 30, 2023 and December 31, 2022, the SPV had net accounts receivable of $2.4 billion and $3.6 billion, respectively, and outstanding borrowings of $985 million and $1.2 billion, respectively, under the Receivables Securitization Program. For more information, see Note 4 below. 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 orders for the first and second AB 1054 securitization transactions, the Utility sold its right to receive revenues from the non-bypassable wildfire hardening fixed recovery charges (“Recovery Property”) to PG&E Recovery Funding LLC, which, in turn, issued two separate series of recovery bonds secured by separate Recovery Property. 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 six months ended June 30, 2023 or is expected to be provided in the future that was not previously contractually required. As of June 30, 2023 and December 31, 2022, PG&E Recovery Funding LLC had outstanding borrowings of $1.8 billion, included in Long-term debt and Long-term debt, classified as current on the Condensed Consolidated Balance Sheets. SB 901 Securitization PG&E Wildfire 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 the first and second SB 901 securitization transactions, the Utility sold its right to receive revenues from the non-bypassable fixed recovery charges (“SB 901 Recovery Property”) to PG&E Wildfire Recovery Funding LLC, which, in turn, issued two separate series of recovery bonds secured by separate SB 901 Recovery Property. PG&E Wildfire 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 Wildfire Recovery Funding LLC are decisions made by the servicer of the SB 901 Recovery Property. The Utility is considered the primary beneficiary and consolidates PG&E Wildfire Recovery Funding LLC as it acts in this role as servicer. No additional financial support was provided to PG&E Wildfire Recovery Funding LLC during the six months ended June 30, 2023 or is expected to be provided in the future that was not previously contractually required. As of June 30, 2023 and December 31, 2022, PG&E Wildfire Recovery Funding LLC had outstanding borrowings of $7.4 billion and $7.5 billion, respectively, included in Long-term debt and Long-term debt, classified as current on the Condensed Consolidated Balance Sheets. For more information, see Note 5 below. Non-Consolidated VIEs Power Purchase Agreement s 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 as of June 30, 2023, 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 or 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 as of June 30, 2023, it did not consolidate any of them. The Lakeside Building BA2 300 Lakeside LLC, a wholly owned subsidiary of TMG Bay Area Investments II, LLC, and the Utility are parties to an office lease agreement for approximately 910,000 rentable square feet of space within the Lakeside Building which serves as the Utility’s principal administrative headquarters. BA2 300 Lakeside LLC is considered a VIE because the group that holds the equity investment at risk lacks the right to receive the expected residual returns of the entity due to a fixed-price purchase option covering more than 50% of the fair value of the assets held by the entity. The most significant activities that impact the economic performance of BA2 300 Lakeside LLC are decisions related to significant maintenance and remarketing of the property. The Utility is not considered the primary beneficiary and does not consolidate BA2 300 Lakeside LLC as it does not have any decision-making rights associated with these activities. The Utility’s financial obligation is limited to issued letters of credit as well as the amounts it pays for base rent and certain costs, per the office lease agreement. For more information, see “Oakland Headquarters Lease and Purchase” in Note 11 below.
Pension and Other Post-Retirement Benefits	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.Non-service costs are reflected in Other income, net on the Condensed Consolidated Statements of Income. Service costs are reflected in Operating and maintenance on the Condensed Consolidated Statements of Income.
Earnings Per Share	PG&E Corporation’s basic EPS is calculated by dividing the income 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.
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 Condensed 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 Condensed 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 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 Condensed Consolidated Balance Sheets at fair value.

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	6 Months Ended
	Jun. 30, 2023
Accounting Policies [Abstract]
Summary of Revenues Disaggregated by Type of Customer	The following table presents the Utility’s revenues disaggregated by type of customer: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2023 2022 2023 2022 Electric Revenue from contracts with customers Residential $ 1,404 $ 1,213 $ 2,693 $ 2,707 Commercial 1,283 1,252 2,427 2,425 Industrial 375 322 728 672 Agricultural 314 484 469 700 Public street and highway lighting 20 19 39 37 Other, net (1) (121) (77) (78) (90) Total revenue from contracts with customers - electric 3,275 3,213 6,278 6,451 Regulatory balancing accounts (2) 577 477 1,693 1,397 Total electric operating revenue $ 3,852 $ 3,690 $ 7,971 $ 7,848 Natural gas Revenue from contracts with customers Residential $ 691 $ 388 $ 2,574 $ 1,851 Commercial 189 197 702 541 Transportation service only 398 356 842 755 Other, net (1) (257) (88) (410) (267) Total revenue from contracts with customers - gas 1,021 853 3,708 2,880 Regulatory balancing accounts (2) 417 575 (180) 188 Total natural gas operating revenue 1,438 1,428 3,528 3,068 Total operating revenues $ 5,290 $ 5,118 $ 11,499 $ 10,916 (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 Net Benefit Costs	The net periodic benefit costs reflected in PG&E Corporation’s Condensed Consolidated Financial Statements for the three and six months ended June 30, 2023 and 2022 were as follows: Pension Benefits Other Benefits Three Months Ended June 30, (in millions) 2023 2022 2023 2022 Service cost for benefits earned (1) $ 95 $ 144 $ 9 $ 16 Interest cost 229 173 19 14 Expected return on plan assets (246) (298) (33) (33) Amortization of prior service cost (1) (1) — 1 Amortization of net actuarial (gain) loss — 1 (4) (10) Net periodic benefit cost 77 19 (9) (12) Regulatory account transfer (2) (6) 64 — — Total $ 71 $ 83 $ (9) $ (12) (1) A portion of service costs is capitalized pursuant to GAAP. (2) The Utility recorded these amounts to a regulatory account since they are probable of recovery from, or refund to, customers in future rates. Pension Benefits Other Benefits Six Months Ended June 30, (in millions) 2023 2022 2023 2022 Service cost for benefits earned (1) $ 190 $ 288 $ 19 $ 31 Interest cost 457 346 37 27 Expected return on plan assets (491) (595) (66) (65) Amortization of prior service cost (2) (2) 1 3 Amortization of net actuarial (gain) loss — 1 (9) (20) Net periodic benefit cost 154 38 (18) (24) Regulatory account transfer (2) (13) 127 — — Total $ 141 $ 165 $ (18) $ (24) (1) A portion of service costs is capitalized pursuant to GAAP. (2) The Utility recorded these amounts to a regulatory account since they are probable of recovery from, or refund to, customers in future rates.
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) consisted of the following: Pension Other Customer Credit Trust Total (in millions, net of income tax) Three Months Ended June 30, 2023 Beginning balance $ (12) $ 18 $ (1) $ 5 Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1, $0 and $0, respectively) — — — — Amortization of net actuarial gain (net of taxes of $0, $1 and $0, respectively) — (3) — (3) Regulatory account transfer (net of taxes of $1, $1 and $0, respectively) — 3 — 3 Net current period other comprehensive gain — — — — Ending balance $ (12) $ 18 $ (1) $ 5 (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. See the “Pension and Other Post-Retirement Benefits” table above for additional details. Pension Benefits Other Customer Credit Trust Total (in millions, net of income tax) Three Months Ended June 30, 2022 Beginning balance $ (33) $ 18 $ — $ (15) Other comprehensive income before reclassification Loss on investments (net of taxes of $0, $0 and $2, respectively) — — (5) (5) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $0, $0 and $0, respectively) (1) 1 — — Amortization of net actuarial (gain) loss (net of taxes of $0, $3 and $0, respectively) 1 (7) — (6) Regulatory account transfer (net of taxes of $0, $3 and $0, respectively) — 6 — 6 Net current period other comprehensive loss — — (5) (5) Ending balance $ (33) $ 18 $ (5) $ (20) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. See the “Pension and Other Post-Retirement Benefits” table above for additional details. Pension Other Customer Credit Trust Total (in millions, net of income tax) Six Months Ended June 30, 2023 Beginning balance $ (12) $ 18 $ (6) $ — Other comprehensive income before reclassification Gain on investments (net of taxes of $0, $0 and $2, respectively) — — 5 5 Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1, $0 and $0, respectively) (1) 1 — — Amortization of net actuarial gain (net of taxes of $0, $2 and $0, respectively) — (7) — (7) Regulatory account transfer (net of taxes of $1, $2 and $0, respectively) 1 6 — 7 Net current period other comprehensive gain — — 5 5 Ending balance $ (12) $ 18 $ (1) $ 5 (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. See the “Pension and Other Post-Retirement Benefits” table above for additional details. Pension Other Customer Credit Trust Total (in millions, net of income tax) Six Months Ended June 30, 2022 Beginning balance $ (33) $ 18 $ — $ (15) Other comprehensive income before reclassification Loss on investments (net of taxes of $0, $0 and $2, respectively) — — (5) (5) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $0, $1 and$0, respectively) (2) 2 — — Amortization of net actuarial (gain) loss (net of taxes of $0, $6 and $0, respectively) 1 (14) — (13) Regulatory account transfer (net of taxes of $0, $5 and $0, respectively) 1 12 — 13 Net current period other comprehensive loss — — (5) (5) Ending balance $ (33) $ 18 $ (5) $ (20) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. See the “Pension and Other Post-Retirement Benefits” table above for additional details.

REGULATORY ASSETS, LIABILITIE_2

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Tables)	6 Months Ended
	Jun. 30, 2023
Regulated Operations [Abstract]
Long-Term Regulatory Assets	Long-term regulatory assets are comprised of the following: Balance at (in millions) June 30, 2023 December 31, 2022 Pension benefits (1) $ 109 $ 120 Environmental compliance costs 1,204 1,193 Utility retained generation (2) 63 86 Price risk management 164 177 Catastrophic event memorandum account (3) 1,272 1,085 Wildfire expense memorandum account (4) 468 439 Fire hazard prevention memorandum account (5) 86 79 Fire risk mitigation memorandum account (6) 23 65 Wildfire mitigation plan memorandum account (7) 654 756 Deferred income taxes (8) 3,100 2,730 Insurance premium costs (9) 11 99 Wildfire mitigation balancing account (10) 252 327 Vegetation management balancing account (11) 1,652 2,276 COVID-19 pandemic protection memorandum accounts (12) 18 26 Microgrid memorandum account (13) 141 213 Financing costs (14) 203 211 SB 901 securitization (15) 5,296 5,378 AROs in excess of recoveries (16) — 120 Other 1,247 1,063 Total long-term regulatory assets $ 15,963 $ 16,443 (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. The increase in the CEMA regulatory asset from December 31, 2022 to June 30, 2023 is primarily due to costs incurred for repair and restoration work performed related to an increase in declared winter storm events in the Utility’s service area. As of June 30, 2023 and December 31, 2022, $45 million and $44 million in COVID-19 related costs were recorded to CEMA regulatory assets, respectively. Recovery of CEMA costs is subject to CPUC review and approval. (4) Represents incremental wildfire claims and outside legal expenses related to the 2021 Dixie fire and the 2022 Mosquito fire. 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 incremental costs associated with fire risk mitigation. Recovery of FRMMA costs is subject to CPUC review and approval. (7) Includes costs associated with the 2020 WMP for the period of January 1, 2020 through December 31, 2020, the 2021 WMP for the period of January 1, 2021 through December 31, 2021, the 2022 WMP for the period of January 1, 2022 through December 31, 2022, and the 2023 WMP for the period of January 1, 2023 through June 30, 2023. Also includes the noncurrent portion of costs associated with the 2019 WMP that were approved for recovery per the 2020 WMCE final decision. 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 of January 1, 2020 through June 30, 2023. The noncurrent balance represents costs above 115% of adopted revenue requirements, which are subject to CPUC review and approval. (11) Includes costs associated with certain vegetation management activities for the period of January 1, 2020 through June 30, 2023. The noncurrent balance represents costs above 120% of adopted revenue requirements, which are subject to CPUC review and approval. (12) Includes costs associated with customer protections, including higher uncollectible costs related to the moratorium on electric and gas service disconnections program implementation costs, and higher accounts receivable financing costs for the period of March 4, 2020 to September 30, 2021. As of June 30, 2023, the Utility had recorded uncollectibles in the amount of $4 million for small business customers. The remaining $14 million is associated with program costs and higher accounts receivable financing costs. As of December 31, 2022, the Utility had recorded uncollectibles in the amount of $4 million for small business customers. The remaining $22 million is associated with program costs and higher accounts receivable financing costs. Recovery of CPPMA costs is subject to CPUC review and approval. (13) Includes costs associated with temporary generation, infrastructure upgrades, and community grid enablement programs associated with the implementation of microgrids. Amounts incurred are subject to CPUC review and approval. (14) Includes costs associated with long-term debt financing deemed recoverable under ASC 980 more than twelve months from the current date. These costs and their amortization period are reviewable and approved in the Utility’s cost of capital or other regulatory filings. (15) In connection with the SB 901 securitization, the CPUC authorized the issuance of one or more series of recovery bonds in connection with the post-emergence transaction to finance $7.5 billion of claims associated with the 2017 Northern California wildfires. The balance represents PG&E Wildfire Recovery Funding LLC’s right to recover $7.5 billion in wildfire claims costs associated with the 2017 Northern California wildfires, partially offset by the $2.0 billion in required upfront shareholder contributions to the customer credit trust, net of amortization since inception. The recovery bonds are being paid through fixed recovery charges, which are designed to recover the full scheduled principal amount of the recovery bonds along with any associated interest and financing costs. See Note 5 below. (16) 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 asset also represents the deferral of realized and unrealized gains and losses on these nuclear decommissioning trust investments. See Note 9 below.
Long-Term Regulatory Liabilities	Long-term regulatory liabilities are comprised of the following: Balance at (in millions) June 30, 2023 December 31, 2022 Cost of removal obligations (1) $ 8,023 $ 7,773 Public purpose programs (2) 1,225 1,062 Employee benefit plans (3) 918 904 Transmission tower wireless licenses (4) 421 430 SFGO sale (5) 224 264 SB 901 securitization (6) 6,127 5,800 Wildfire self-insurance (7) 200 — Other 1,380 1,397 Total long-term regulatory liabilities $ 18,518 $ 17,630 (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 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. (3) Represents cumulative differences between incurred costs and amounts collected in rates for post-retirement medical, post-retirement life and long-term disability plans. (4) Represents the portion of the net proceeds received from the sale of transmission tower wireless licenses that will be returned to customers through 2042. Of the $421 million, $294 million will be refunded to FERC-jurisdictional customers, and $127 million will be refunded to CPUC-jurisdictional customers. (5) 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 that began in 2022. (6) In connection with the SB 901 securitization, the Utility is required to return up to $7.59 billion of certain shareholder tax benefits to customers via periodic bill credits over the life of the recovery bonds. The balance reflects qualifying shareholder tax benefits that PG&E Corporation is obligated to contribute to the customer credit trust, net of amortization since inception, and is expected to increase as additional qualifying amounts are recognized, including when the Fire Victim Trust sells additional shares. PG&E Corporation will continue to separately recognize tax benefits within income tax expense on the income statement when the Fire Victim Trust sells additional shares. See Note 5 below. (7) Represents amounts received from customers designated for wildfire self-insurance. See Note 10 below.
Current Regulatory Balancing Accounts Receivable	Current regulatory balancing accounts receivable and payable are comprised of the following: Balance at (in millions) June 30, 2023 December 31, 2022 Electric distribution (1) $ 1,289 $ 448 Electric transmission (2) 117 96 Gas distribution and transmission (3) 62 72 Energy procurement (4) 1,032 684 Public purpose programs (5) 300 358 Fire hazard prevention memorandum account (6) 129 — Wildfire mitigation plan memorandum account (7) 78 — Wildfire mitigation balancing account (8) 96 2 Vegetation management balancing account (9) 872 137 Insurance premium costs (10) 268 602 Residential uncollectibles balancing accounts (11) 228 126 Catastrophic event memorandum account (12) 332 144 Other 580 595 Total regulatory balancing accounts receivable $ 5,383 $ 3,264
Current Regulatory Balancing Accounts Payable	Balance at (in millions) June 30, 2023 December 31, 2022 Electric transmission (2) $ 222 $ 228 Gas distribution and transmission (3) 449 66 Energy procurement (4) 8 428 Public purpose programs (5) 257 272 SFGO sale 75 152 Other 306 512 Total regulatory balancing accounts payable $ 1,317 $ 1,658 (1) The electric distribution accounts track the collection of revenue requirements approved in the GRC and other proceedings. (2) The electric transmission accounts track recovery of costs related to the transmission of electricity approved in the FERC TO rate cases. (3) The gas distribution and transmission accounts track the collection of revenue requirements approved in the GRC and the GT&S rate case and other proceedings. (4) Energy procurement balancing accounts track recovery of costs related to the procurement of electricity and other revenue requirements approved by the CPUC for recovery in procurement-related balancing accounts, including any environmental compliance-related activities. (5) The Public purpose programs balancing accounts are primarily used to record and recover authorized revenue requirements for CPUC-mandated programs such as energy efficiency. (6) The FHPMA tracks costs associated with the implementation of regulations and requirements adopted to protect the public from potential fire hazards approved for cost recovery in the 2020 WMCE final decision. (7) The WMPMA tracks costs associated with the 2019 WMP which were approved for cost recovery in the 2020 WMCE final decision. (8) The WMBA tracks costs associated with wildfire mitigation revenue requirement activities approved for cost recovery. (9) The VMBA tracks routine and enhanced vegetation management activities approved for cost recovery. (10) 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, as of June 30, 2023, and December 31, 2022 there were $7 million and $48 million, respectively, in insurance premium costs recorded in Current regulatory assets. (11) The RUBA tracks costs associated with customer protections, including higher uncollectible costs related to a moratorium on electric and gas service disconnections for residential customers. (12) The CEMA tracks costs associated with responding to catastrophic events that have been declared a disaster or state of emergency by competent federal or state authorities approved for cost recovery in the 2018 CEMA and 2020 WMCE final decisions.

DEBT (Tables)

DEBT (Tables)	6 Months Ended
	Jun. 30, 2023
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 as of June 30, 2023: (in millions) Termination Maximum Facility Limit Loans Outstanding Letters of Credit Outstanding Facility Utility revolving credit facility June 2028 $ 4,400 (1) $ — $ (697) $ 3,703 Utility Receivables Securitization Program (2) June 2025 985 (3) (985) — — (3) PG&E Corporation revolving credit facility June 2026 500 — — 500 Total credit facilities $ 5,885 $ (985) $ (697) $ 4,203 (1) Includes a $2.0 billion letter of credit sublimit. (2) For more information on the Receivables Securitization Program, see “Variable Interest Entities” in Note 2 above. (3) 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 limit fluctuates between $1.25 billion and $1.5 billion depending on the periods set forth in the transaction documents. Further, 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.

SB 901 SECURITIZATION AND CUS_2

SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST (Tables)	6 Months Ended
	Jun. 30, 2023
Debt Disclosure [Abstract]
Schedule of Financial Statement Impact of Securitization	The following tables illustrate the changes in the SB 901 securitization’s impact on the Utility’s regulatory assets and liabilities since December 31, 2022: SB 901 securitization regulatory asset (in millions) Balance at December 31, 2022 $ 5,378 Amortization (82) Balance at June 30, 2023 $ 5,296 SB 901 securitization regulatory liability (in millions) Balance at December 31, 2022 $ (5,800) Amortization 240 Additions (1) (567) Balance at June 30, 2023 $ (6,127)

EARNINGS PER SHARE (Tables)

EARNINGS PER SHARE (Tables)	6 Months Ended
	Jun. 30, 2023
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Diluted, by Common Class, Including Two Class Method	The following is a reconciliation of PG&E Corporation’s income available for common shareholders and weighted average common shares outstanding for calculating diluted EPS: Three Months Ended June 30, Six Months Ended June 30, (in millions, except per share amounts) 2023 2022 2023 2022 Income available for common shareholders $ 406 $ 356 $ 975 $ 831 Weighted average common shares outstanding, basic 2,019 1,987 2,005 1,987 Add incremental shares from assumed conversions: Employee share-based compensation 6 8 6 8 Equity Units 114 146 126 146 Weighted average common shares outstanding, diluted 2,139 2,141 2,137 2,141 Total income per common share, diluted $ 0.19 $ 0.17 $ 0.46 $ 0.39

DERIVATIVES (Tables)

DERIVATIVES (Tables)	6 Months Ended
	Jun. 30, 2023
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 Underlying Product Instruments June 30, 2023 December 31, 2022 Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 246,078,190 171,212,813 Options 44,745,000 27,785,000 Electricity (MWh) Forwards, Futures and Swaps 9,389,471 10,814,728 Options 277,200 215,600 Congestion Revenue Rights (3) 180,123,433 205,743,505 (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.
Offsetting Liabilities	As of June 30, 2023, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 147 $ (11) $ 31 $ 167 Other noncurrent assets – other 239 — — 239 Current liabilities – other (80) 11 16 (53) Noncurrent liabilities – other (164) — 1 (163) Total commodity risk $ 142 $ — $ 48 $ 190 As of December 31, 2022, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 824 $ (170) $ 537 $ 1,191 Other noncurrent assets – other 306 — — 306 Current liabilities – other (238) 170 16 (52) Noncurrent liabilities – other (177) — — (177) Total commodity risk $ 715 $ — $ 553 $ 1,268
Offsetting Assets	As of June 30, 2023, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 147 $ (11) $ 31 $ 167 Other noncurrent assets – other 239 — — 239 Current liabilities – other (80) 11 16 (53) Noncurrent liabilities – other (164) — 1 (163) Total commodity risk $ 142 $ — $ 48 $ 190 As of December 31, 2022, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 824 $ (170) $ 537 $ 1,191 Other noncurrent assets – other 306 — — 306 Current liabilities – other (238) 170 16 (52) Noncurrent liabilities – other (177) — — (177) Total commodity risk $ 715 $ — $ 553 $ 1,268

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	6 Months Ended
	Jun. 30, 2023
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 June 30, 2023 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 723 $ — $ — $ — $ 723 Nuclear decommissioning trusts Short-term investments 126 — — — 126 Global equity securities 2,035 — — — 2,035 Fixed-income securities 1,195 793 — — 1,988 Assets measured at NAV — — — — 29 Total nuclear decommissioning trusts (2) 3,356 793 — — 4,178 Customer credit trust Short-term investments 7 — — — 7 Global equity securities 148 — — — 148 Fixed-income securities 85 236 — — 321 Total customer credit trust 240 236 — — 476 Price risk management instruments (Note 8) Electricity — 28 330 11 369 Gas — 28 — 9 37 Total price risk management instruments — 56 330 20 406 Rabbi trusts Short-term investments 97 — — — 97 Global equity securities 5 — — — 5 Life insurance contracts — 65 — — 65 Total rabbi trusts 102 65 — — 167 Long-term disability trust Short-term investments 7 — — — 7 Assets measured at NAV — — — — 117 Total long-term disability trust 7 — — — 124 TOTAL ASSETS $ 4,428 $ 1,150 $ 330 $ 20 $ 6,074 Liabilities: Price risk management instruments (Note 8) Electricity $ — $ 31 $ 204 $ (26) $ 209 Gas — 9 — (2) 7 TOTAL LIABILITIES $ — $ 40 $ 204 $ (28) $ 216 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. (2) Represents amount before deducting $654 million primarily related to deferred taxes on appreciation of investment value. Fair Value Measurements December 31, 2022 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 658 $ — $ — $ — $ 658 Fixed-income securities — 49 — — 49 Nuclear decommissioning trusts Short-term investments 117 — — — 117 Global equity securities 1,845 — — — 1,845 Fixed-income securities 1,094 791 — — 1,885 Assets measured at NAV — — — — 25 Total nuclear decommissioning trusts (2) 3,056 791 — — 3,872 Customer credit trust Short-term investments 19 — — — 19 Global equity securities 218 — — — 218 Fixed-income securities 216 292 — — 508 Total customer credit trust 453 292 — — 745 Price risk management instruments (Note 8) Electricity — 94 432 40 566 Gas — 604 — 327 931 Total price risk management instruments — 698 432 367 1,497 Rabbi trusts Short-term investments 25 — — — 25 Global equity securities 5 — — — 5 Fixed-income securities — 69 — — 69 Life insurance contracts — 64 — — 64 Total rabbi trusts 30 133 — — 163 Long-term disability trust Short-term investments 10 — — — 10 Assets measured at NAV — — — — 133 Total long-term disability trust 10 — — — 143 TOTAL ASSETS $ 4,207 $ 1,963 $ 432 $ 367 $ 7,127 Liabilities: Price risk management instruments (Note 8) Electricity $ — $ 10 $ 233 $ (20) $ 223 Gas — 172 — (166) 6 TOTAL LIABILITIES $ — $ 182 $ 233 $ (186) $ 229 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. (2) Represents amount before deducting $575 million, primarily related to deferred taxes on appreciation of investment value.
Fair Value Measurement Inputs and Valuation Techniques	Fair Value at (in millions) At June 30, 2023 Valuation Unobservable Fair Value Measurement Assets Liabilities Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 272 $ 121 Market approach CRR auction prices $ (145.09) - 843.59 / 0.92 Power purchase agreements $ 58 $ 83 Discounted cash flow Forward prices $ (7.91) - 263.13 / 64.94 (1) Represents price per MWh. (2) Unobservable inputs were weighted by the relative fair value of the instruments. Fair Value at (in millions) At December 31, 2022 Valuation Unobservable Fair Value Measurement Assets Liabilities Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 305 $ 138 Market approach CRR auction prices $ (145.09) - 2,724.93 / 0.89 Power purchase agreements $ 127 $ 95 Discounted cash flow Forward prices $ (6.39) - 286.75 / 78.14 (1) Represents price per MWh. (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 three and six months ended June 30, 2023 and 2022, respectively: Price Risk Management Instruments (in millions) 2023 2022 Asset (Liability) balance as of April 1 $ 212 $ (24) Net realized and unrealized gains (losses): Included in regulatory assets and liabilities or balancing accounts (1) (86) 35 Asset balance as of June 30 $ 126 $ 11 (1) The costs related to price risk management activities are recovered through rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted. Price Risk Management Instruments (in millions) 2023 2022 Asset (Liability) balance as of January 1 $ 199 $ (34) Net realized and unrealized gains (losses): Included in regulatory assets and liabilities or balancing accounts (1) (73) 45 Asset balance as of June 30 $ 126 $ 11 (1) The costs related to price risk management activities are recovered through 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 June 30, 2023 At December 31, 2022 (in millions) Carrying Amount Level 2 Fair Value Carrying Amount Level 2 Fair Value Debt (Note 4) PG&E Corporation $ 4,430 $ 4,489 $ 4,355 $ 4,490 Utility 35,625 30,473 32,847 27,666
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 June 30, 2023 Nuclear decommissioning trusts Short-term investments $ 126 $ — $ — $ 126 Global equity securities 391 1,684 (11) 2,064 Fixed-income securities 2,083 14 (109) 1,988 Total (1) $ 2,600 $ 1,698 $ (120) $ 4,178 As of December 31, 2022 Nuclear decommissioning trusts Short-term investments $ 117 $ — $ — $ 117 Global equity securities 413 1,468 (11) 1,870 Fixed-income securities 1,991 10 (116) 1,885 Total (1) $ 2,521 $ 1,478 $ (127) $ 3,872 (1) Represents amounts before deducting $654 million and $575 million as of June 30, 2023 and December 31, 2022, respectively, primarily related to deferred taxes on appreciation of investment value.
Schedule of Available for Sale Securities Table	The fair value of fixed-income securities by contractual maturity is as follows: As of (in millions) June 30, 2023 Less than 1 year $ 22 1–5 years 627 5–10 years 497 More than 10 years 842 Total maturities of fixed-income securities $ 1,988 The following table provides a summary of equity securities and available-for-sale debt securities: (in millions) Amortized Total Total Total Fair As of June 30, 2023 Customer credit trust Short-term investments $ 7 $ — $ — $ 7 Global equity securities 129 23 (4) 148 Fixed-income securities 323 — (2) 321 Total $ 459 $ 23 $ (6) $ 476 As of December 31, 2022 Customer credit trust Short-term investments $ 19 $ — $ — $ 19 Global equity securities 219 13 (14) 218 Fixed-income securities 516 — (8) 508 Total $ 754 $ 13 $ (22) $ 745
Schedule of Activity for Debt and Equity Securities	The following table provides a summary of activity for the fixed-income and equity securities: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2023 2022 2023 2022 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 474 $ 948 $ 751 $ 1,369 Gross realized gains on securities 37 81 42 137 Gross realized losses on securities (10) (58) (18) (65) The fair value of fixed-income securities by contractual maturity is as follows: As of (in millions) June 30, 2023 Less than 1 year $ — 1–5 years 88 5–10 years 80 More than 10 years 153 Total maturities of fixed-income securities $ 321 The following table provides a summary of activity for the fixed-income and equity securities: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2023 2022 2023 2022 Proceeds from sales and maturities of customer credit trust investments $ 135 $ — $ 304 $ — Gross realized gains on securities 6 1 8 1 Gross realized losses on securities (1) (5) (8) (10) (8) (1) Includes $4.3 million of impaired debt securities which were written down to their respective fair values during the three and six months ended June 30, 2023.

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES (Tables)	6 Months Ended
	Jun. 30, 2023
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, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 650 Accrued Losses — Payments (192) Balance at June 30, 2023 $ 458 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, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 32 Accrued Losses — Payments (13) Balance at June 30, 2023 $ 19 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 2021 Dixie fire since December 31, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 1,131 Accrued Losses — Payments (447) Balance at June 30, 2023 $ 684 Total probable recoveries for the 2021 Dixie fire and the 2022 Mosquito fire as of June 30, 2023 are: Potential Recovery Source (in millions) 2022 Mosquito fire 2021 Dixie fire Insurance $ 54 $ 528 FERC TO rates (1) 9 117 WEMA (1) 51 411 Wildfire Fund — 175 Probable recoveries at June 30, 2023 $ 114 $ 1,231 (1) Includes legal costs. The balances for insurance receivables with respect to wildfires are included in Other accounts receivable in PG&E Corporation’s and the Utility’s Condensed Consolidated Balance Sheets: Insurance Receivable (in millions) 2022 Mosquito fire 2021 Dixie fire 2020 Zogg fire 2019 Kincade fire Total Balance at December 31, 2022 $ 45 $ 530 $ 118 $ 101 $ 794 Accrued insurance recoveries (1) 8 (1) 1 — 8 Reimbursements — (200) (54) (101) (355) Balance at June 30, 2023 $ 53 $ 329 $ 65 $ — $ 447 (1) For the six months ended June 30, 2023, the accrued insurance recoveries decreased for the 2021 Dixie fire with a corresponding increase to the 2020 Zogg fire for $1 million.

OTHER CONTINGENCIES AND COMMI_2

OTHER CONTINGENCIES AND COMMITMENTS (Tables)	6 Months Ended
	Jun. 30, 2023
Commitments and Contingencies Disclosure [Abstract]
Schedule of Environmental Remediation Liability	The Utility’s environmental remediation liability is primarily included in non-current liabilities on the Condensed Consolidated Balance Sheets and is comprised of the following: Balance at (in millions) June 30, 2023 December 31, 2022 Topock natural gas compressor station $ 291 $ 284 Hinkley natural gas compressor station 106 110 Former MGP sites owned by the Utility or third parties (1) 839 750 Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites (2) 119 112 Fossil fuel-fired generation facilities and sites (3) 25 26 Total environmental remediation liability $ 1,380 $ 1,282 (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.

ORGANIZATION AND BASIS OF PRE_2

ORGANIZATION AND BASIS OF PRESENTATION (Details)	6 Months Ended
	Jun. 30, 2023 numberOfSegment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of operating segments (segment)	1

SUMMARY OF SIGNIFICANT ACCOUN_4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - 10Q Narrative (Details) ft² in Thousands			3 Months Ended		6 Months Ended		8 Months Ended
	Nov. 17, 2022 USD ($)	Oct. 18, 2022 USD ($)	Jun. 30, 2023 USD ($) ft²	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($) ft²	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($) ft²	Dec. 31, 2022 USD ($)
Public Utility, Property, Plant and Equipment [Line Items]
Period for probable revenue recovery					24 months
Credit losses			$ 154,000,000	$ 33,000,000	$ 293,000,000	$ 76,000,000
Government Assistance, Statement of Income or Comprehensive Income [Extensible Enumeration]					Operating and maintenance
Litigation liability, current			193,000,000		$ 193,000,000		$ 193,000,000
Wildfire Fund asset			460,000,000		460,000,000		460,000,000	$ 460,000,000
Litigation contribution, net			4,600,000,000		4,600,000,000		4,600,000,000
Amortization and accretion			117,000,000	117,000,000	234,000,000	235,000,000
Insurance receivable			447,000,000		447,000,000		447,000,000	794,000,000
Performance-Based Disbursement
Public Utility, Property, Plant and Equipment [Line Items]
Disbursement		$ 7
Maximum disbursement		300,000,000
Performance-Based Disbursement | Utilities Operating Expense, Maintenance and Operations
Public Utility, Property, Plant and Equipment [Line Items]
Reimbursement amount							52,000,000
Civil Nuclear Credit Program
Public Utility, Property, Plant and Equipment [Line Items]
Disbursement	$ 1,100,000,000
Civil Nuclear Credit Program | Utilities Operating Expense, Maintenance and Operations
Public Utility, Property, Plant and Equipment [Line Items]
Reimbursement amount			34,000,000		34,000,000
Civil Nuclear Credit Program | Cost of Goods and Services Sold, Electricity
Public Utility, Property, Plant and Equipment [Line Items]
Reimbursement amount			48,000,000		48,000,000
Regulatory Balancing Accounts Receivable
Public Utility, Property, Plant and Equipment [Line Items]
Total regulatory balancing accounts			5,383,000,000		5,383,000,000		5,383,000,000	3,264,000,000
Regulatory Balancing Accounts Receivable | Residential uncollectibles balancing accounts
Public Utility, Property, Plant and Equipment [Line Items]
Total regulatory balancing accounts			228,000,000		228,000,000		228,000,000	126,000,000
COVID-19 Pandemic protection memorandum account
Public Utility, Property, Plant and Equipment [Line Items]
Regulatory assets			4,000,000		4,000,000		4,000,000
FERC
Public Utility, Property, Plant and Equipment [Line Items]
Regulatory assets			42,000,000		42,000,000		42,000,000
2021 Dixie fire
Public Utility, Property, Plant and Equipment [Line Items]
Insurance receivable			$ 329,000,000		$ 329,000,000		$ 329,000,000	530,000,000
Wildfire Fund Asset
Public Utility, Property, Plant and Equipment [Line Items]
Finite-lived intangible asset, useful life			15 years		15 years		15 years
Long-Term Debt | Performance-Based Disbursement
Public Utility, Property, Plant and Equipment [Line Items]
Reimbursement amount							$ 245,000,000
Other Current Liabilities
Public Utility, Property, Plant and Equipment [Line Items]
Wildfire fund, noncurrent			$ 939,000,000		$ 939,000,000		939,000,000
Other Current Liabilities | Performance-Based Disbursement
Public Utility, Property, Plant and Equipment [Line Items]
Reimbursement amount							15,000,000
Other noncurrent assets – other | 2021 Dixie fire
Public Utility, Property, Plant and Equipment [Line Items]
Insurance receivable			175,000,000		175,000,000		175,000,000
Pacific Gas & Electric Co (Utility)
Public Utility, Property, Plant and Equipment [Line Items]
Wildfire Fund asset			460,000,000		460,000,000		$ 460,000,000	460,000,000
Amortization and accretion			$ 117,000,000	$ 117,000,000	$ 234,000,000	$ 235,000,000
Pacific Gas & Electric Co (Utility) | The Lakeside Building
Public Utility, Property, Plant and Equipment [Line Items]
Rentable square feet | ft²			910		910		910
Receivables Securitization Program | Pacific Gas & Electric Co (Utility)
Public Utility, Property, Plant and Equipment [Line Items]
Outstanding borrowings			$ 985,000,000		$ 985,000,000		$ 985,000,000	1,200,000,000
Receivables Securitization Program | PG&E AR Facility, LLC (SPV)
Public Utility, Property, Plant and Equipment [Line Items]
Accounts receivable, net			2,400,000,000		2,400,000,000		2,400,000,000	3,600,000,000
Recovery Bonds | Secured Debt
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount			1,800,000,000		1,800,000,000		1,800,000,000	1,800,000,000
SB 901 Securitization | Secured Debt
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount			$ 7,400,000,000		$ 7,400,000,000		$ 7,400,000,000	$ 7,500,000,000
Senate Bill 846 | Pacific Gas & Electric Co (Utility)
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount		1,100,000,000
Senate Bill 846 | Pacific Gas & Electric Co (Utility) | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount		$ 1,400,000,000

SUMMARY OF SIGNIFICANT ACCOUN_5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Revenues Disaggregated by Type of Customer) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Disaggregation of Revenue [Abstract]
Total operating revenues	$ 5,290	$ 5,118	$ 11,499	$ 10,916
Electric
Disaggregation of Revenue [Abstract]
Total operating revenues	3,852	3,690	7,971	7,848
Natural gas
Disaggregation of Revenue [Abstract]
Total operating revenues	1,438	1,428	3,528	3,068
Pacific Gas & Electric Co (Utility)
Disaggregation of Revenue [Abstract]
Total operating revenues	5,290	5,118	11,499	10,916
Pacific Gas & Electric Co (Utility) | Electric
Disaggregation of Revenue [Abstract]
Total operating revenues	3,275	3,213	6,278	6,451
Regulatory balancing accounts	577	477	1,693	1,397
Total operating revenues	3,852	3,690	7,971	7,848
Pacific Gas & Electric Co (Utility) | Electric | Residential
Disaggregation of Revenue [Abstract]
Total operating revenues	1,404	1,213	2,693	2,707
Pacific Gas & Electric Co (Utility) | Electric | Commercial
Disaggregation of Revenue [Abstract]
Total operating revenues	1,283	1,252	2,427	2,425
Pacific Gas & Electric Co (Utility) | Electric | Industrial
Disaggregation of Revenue [Abstract]
Total operating revenues	375	322	728	672
Pacific Gas & Electric Co (Utility) | Electric | Agricultural
Disaggregation of Revenue [Abstract]
Total operating revenues	314	484	469	700
Pacific Gas & Electric Co (Utility) | Electric | Public street and highway lighting
Disaggregation of Revenue [Abstract]
Total operating revenues	20	19	39	37
Pacific Gas & Electric Co (Utility) | Electric | Other, net
Disaggregation of Revenue [Abstract]
Total operating revenues	(121)	(77)	(78)	(90)
Pacific Gas & Electric Co (Utility) | Natural gas
Disaggregation of Revenue [Abstract]
Total operating revenues	1,021	853	3,708	2,880
Regulatory balancing accounts	417	575	(180)	188
Total operating revenues	1,438	1,428	3,528	3,068
Pacific Gas & Electric Co (Utility) | Natural gas | Residential
Disaggregation of Revenue [Abstract]
Total operating revenues	691	388	2,574	1,851
Pacific Gas & Electric Co (Utility) | Natural gas | Commercial
Disaggregation of Revenue [Abstract]
Total operating revenues	189	197	702	541
Pacific Gas & Electric Co (Utility) | Natural gas | Transportation service only
Disaggregation of Revenue [Abstract]
Total operating revenues	398	356	842	755
Pacific Gas & Electric Co (Utility) | Natural gas | Other, net
Disaggregation of Revenue [Abstract]
Total operating revenues	$ (257)	$ (88)	$ (410)	$ (267)

SUMMARY OF SIGNIFICANT ACCOUN_6

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Components of Net Periodic Benefit Cost) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	$ 95	$ 144	$ 190	$ 288
Interest cost	229	173	457	346
Expected return on plan assets	(246)	(298)	(491)	(595)
Amortization of prior service cost	(1)	(1)	(2)	(2)
Amortization of net actuarial loss	0	1	0	1
Net periodic benefit cost	77	19	154	38
Regulatory account transfer	(6)	64	(13)	127
Net periodic benefit cost	71	83	141	165
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	9	16	19	31
Interest cost	19	14	37	27
Expected return on plan assets	(33)	(33)	(66)	(65)
Amortization of prior service cost	0	1	1	3
Amortization of net actuarial loss	(4)	(10)	(9)	(20)
Net periodic benefit cost	(9)	(12)	(18)	(24)
Regulatory account transfer	0	0	0	0
Net periodic benefit cost	$ (9)	$ (12)	$ (18)	$ (24)

SUMMARY OF SIGNIFICANT ACCOUN_7

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Reclassifications Out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	$ 23,586	$ 21,644	$ 23,075	$ 21,223
Loss on investments		(5)	5	(5)
Net current period other comprehensive gain (loss)	0	(5)	5	(5)
Ending balance	24,015	22,019	24,015	22,019
Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, before reclassification		0	0	0
Loss on investments		0	0	0
Net current period other comprehensive gain (loss)	0	0	0	0
Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, before reclassification		0	0	0
Loss on investments		0	0	0
Net current period other comprehensive gain (loss)	0	0	0	0
Customer Credit Trust
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, before reclassification		2	2	2
Loss on investments		(5)	5	(5)
Net current period other comprehensive gain (loss)	0	(5)	5	(5)
Accumulated Other Comprehensive Income (Loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	5	(15)	0	(15)
Ending balance	5	(20)	5	(20)
Accumulated Other Comprehensive Income (Loss) | Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(12)	(33)	(12)	(33)
Ending balance	(12)	(33)	(12)	(33)
Accumulated Other Comprehensive Income (Loss) | Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	18	18	18	18
Ending balance	18	18	18	18
Accumulated Other Comprehensive Income (Loss) | Customer Credit Trust
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(1)	0	(6)	0
Ending balance	(1)	(5)	(1)	(5)
Amortization of prior service cost
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	0	0	0	0
Amortization of prior service cost | Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, reclassification	1	0	1	0
Amounts reclassified from other comprehensive income	0	(1)	(1)	(2)
Amortization of prior service cost | Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, reclassification	0	0	0	1
Amounts reclassified from other comprehensive income	0	1	1	2
Amortization of prior service cost | Customer Credit Trust
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, reclassification	0	0	0	0
Amounts reclassified from other comprehensive income	0	0	0	0
Amortization of net actuarial loss
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(3)	(6)	(7)	(13)
Amortization of net actuarial loss | Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, reclassification	0	0	0	0
Amounts reclassified from other comprehensive income	0	1	0	1
Amortization of net actuarial loss | Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, reclassification	1	3	2	6
Amounts reclassified from other comprehensive income	(3)	(7)	(7)	(14)
Amortization of net actuarial loss | Customer Credit Trust
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, reclassification	0	0	0	0
Amounts reclassified from other comprehensive income	0	0	0	0
Regulatory account transfer
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	3	6	7	13
Regulatory account transfer | Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, reclassification	1	0	1	0
Amounts reclassified from other comprehensive income	0	0	1	1
Regulatory account transfer | Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, reclassification	1	3	2	5
Amounts reclassified from other comprehensive income	3	6	6	12
Regulatory account transfer | Customer Credit Trust
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, reclassification	0	0	0	0
Amounts reclassified from other comprehensive income	$ 0	$ 0	$ 0	$ 0

REGULATORY ASSETS, LIABILITIE_3

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Assets) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Dec. 31, 2022	Jun. 30, 2022	Feb. 28, 2022
Regulatory Assets [Line Items]
Current regulatory assets	$ 309	$ 296
Regulatory assets	15,963	16,443
Utility retained generation asset costs	1,200
Customer Harm Threshold, post-emergence transaction, recovery bonds issued				$ 7,500
Initial shareholder contribution	2,000
Pacific Gas & Electric Co (Utility)
Regulatory Assets [Line Items]
Current regulatory assets	309	296
Deferred depreciation, interest and tax expense	100
Regulatory assets	15,963	16,443
Pension benefits
Regulatory Assets [Line Items]
Regulatory assets	109	120
Environmental compliance costs
Regulatory Assets [Line Items]
Regulatory assets	1,204	1,193
Utility retained generation
Regulatory Assets [Line Items]
Regulatory assets	63	86
Price risk management
Regulatory Assets [Line Items]
Regulatory assets	164	177
Catastrophic event memorandum account
Regulatory Assets [Line Items]
Regulatory assets	1,272	1,085
Catastrophic event memorandum account | COVID-19
Regulatory Assets [Line Items]
Regulatory assets	45	44
Wildfire expense memorandum account
Regulatory Assets [Line Items]
Regulatory assets	468	439
Fire hazard prevention memorandum account
Regulatory Assets [Line Items]
Regulatory assets	86	79
Fire risk mitigation memorandum account
Regulatory Assets [Line Items]
Regulatory assets	23	65
Wildfire mitigation plan memorandum account
Regulatory Assets [Line Items]
Regulatory assets	654	756
Deferred income taxes
Regulatory Assets [Line Items]
Regulatory assets	3,100	2,730
Insurance premium costs
Regulatory Assets [Line Items]
Regulatory assets	11	99
Wildfire mitigation balancing account
Regulatory Assets [Line Items]
Regulatory assets	$ 252	327
Wildfire mitigation balancing account | Minimum
Regulatory Assets [Line Items]
Cost percentage threshold requiring approval	115%
Vegetation management balancing account
Regulatory Assets [Line Items]
Regulatory assets	$ 1,652	2,276
Cost percentage threshold requiring approval	120%
COVID-19 Pandemic protection memorandum account
Regulatory Assets [Line Items]
Regulatory assets	$ 18	26
COVID-19 pandemic protection memorandum account, undercollection bad debt
Regulatory Assets [Line Items]
Regulatory assets	4	4
COVID-19 pandemic protection memorandum account, program and accounts receivable financing costs
Regulatory Assets [Line Items]
Regulatory assets	14	22
Microgrid memorandum account
Regulatory Assets [Line Items]
Regulatory assets	141	213
Financing costs
Regulatory Assets [Line Items]
Regulatory assets	203	211
SB 901 Securitization
Regulatory Assets [Line Items]
Regulatory assets	5,296	5,378	$ 5,500
Recoveries in excess of AROs
Regulatory Assets [Line Items]
Regulatory assets	0	120
Other
Regulatory Assets [Line Items]
Regulatory assets	$ 1,247	$ 1,063

REGULATORY ASSETS, LIABILITIE_4

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Liabilities) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Dec. 31, 2022	Jun. 30, 2022
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 18,518	$ 17,630
Proceeds received from sale of transmission tower wireless licenses, to be refunded to customers	421
Authorized amount of shareholder tax benefits to be returned	7,590
Federal Energy Regulatory Commission
Regulatory Liabilities [Line Items]
Proceeds received from sale of transmission tower wireless licenses, to be refunded to customers	294
California Public Utilities Commission
Regulatory Liabilities [Line Items]
Proceeds received from sale of transmission tower wireless licenses, to be refunded to customers	127
Cost of removal obligations
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	8,023	7,773
Public purpose programs
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	1,225	1,062
Employee benefit plans
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	918	904
Transmission tower wireless licenses
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	421	430
SFGO sale
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	224	264
SB 901 Securitization
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	6,127	5,800	$ 5,540
Wildfire self-insurance
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	200	0
Other
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 1,380	$ 1,397

REGULATORY ASSETS, LIABILITIE_5

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Current Regulatory Balancing Accounts, Net) (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Regulatory Assets [Line Items]
Regulatory assets	$ 309	$ 296
Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	1,317	1,658
Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	5,383	3,264
Electric distribution | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	1,289	448
Electric transmission | Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	222	228
Electric transmission | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	117	96
Gas distribution and transmission | Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	449	66
Gas distribution and transmission | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	62	72
Energy procurement | Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	8	428
Energy procurement | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	1,032	684
Public purpose programs | Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	257	272
Public purpose programs | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	300	358
Fire hazard prevention memorandum account | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	129	0
Wildfire mitigation plan memorandum account | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	78	0
Wildfire mitigation balancing account | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	96	2
Vegetation management balancing account | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	872	137
Insurance premium costs
Regulatory Assets [Line Items]
Regulatory assets	7	48
Insurance premium costs | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	268	602
Residential uncollectibles balancing accounts | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	228	126
Catastrophic event memorandum account | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	332	144
Other | Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	306	512
Other | Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	580	595
SFGO sale | Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	$ 75	$ 152

DEBT (Outstanding Borrowings an

DEBT (Outstanding Borrowings and Availability) (Details) - USD ($)	Jun. 30, 2023	Jun. 09, 2023	Jun. 08, 2023	Dec. 31, 2022
Revolving Credit Facility
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	$ 5,885,000,000
Loans Outstanding	(985,000,000)
Letters of Credit Outstanding	(697,000,000)
Facility Availability	4,203,000,000
Revolving Credit Facility | PG&E Corporation
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	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	4,400,000,000
Loans Outstanding	0
Letters of Credit Outstanding	(697,000,000)
Facility Availability	3,703,000,000
Letter of credit sublimit	2,000,000,000
Revolving Credit Facility | Pacific Gas & Electric Co (Utility) | Minimum
Debt [Line Items]
Line of credit facility, maximum borrowing capacity		$ 1,250,000,000	$ 1,000,000,000
Receivables Securitization Program | Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	985,000,000
Loans Outstanding	(985,000,000)			$ (1,200,000,000)
Letters of Credit Outstanding	0
Facility Availability	0
Receivables Securitization Program | Pacific Gas & Electric Co (Utility) | Minimum
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	1,250,000,000
Receivables Securitization Program | Pacific Gas & Electric Co (Utility) | Maximum
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	$ 1,500,000,000

DEBT (Narrative) (Details)

DEBT (Narrative) (Details) - Pacific Gas & Electric Co (Utility) - USD ($) $ in Millions	Apr. 18, 2023	Jun. 22, 2023	Jun. 05, 2023	Mar. 30, 2023	Jan. 06, 2023
Letter of Credit Subfacility
Debt [Line Items]
Long-term debt, gross		$ 2,000
Uncommitted Incremental Facility
Debt [Line Items]
Long-term debt, gross		$ 1,000
364-Day 2023 Tranche Loans
Debt [Line Items]
Long-term debt, gross	$ 125
364-Day 2023 Tranche Loans | SOFR
Debt [Line Items]
Credit spread adjustment	0.10%
Basis spread on variable rate	1.375%
364-Day 2023 Tranche Loans | Base Rate
Debt [Line Items]
Basis spread on variable rate	0.375%
First Mortgage Bonds Due 2033
Debt [Line Items]
Debt instrument, face amount			$ 1,150		$ 750
Interest rate			6.40%		6.15%
First Mortgage Bonds Due 2053
Debt [Line Items]
Debt instrument, face amount			$ 500	$ 750	$ 750
Interest rate			6.75%	6.70%	6.75%
First Mortgage Bonds, Stated Maturity 2029
Debt [Line Items]
Debt instrument, face amount			$ 850
Interest rate			6.10%
First Mortgage Bonds, Stated Maturity 2023
Debt [Line Items]
Debt instrument, face amount			$ 375
Interest rate			3.25%
First Mortgage Bonds Due 2023
Debt [Line Items]
Debt instrument, face amount			$ 500
Interest rate			4.25%

SB 901 SECURITIZATION AND CUS_3

SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended		12 Months Ended
	Mar. 31, 2024	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2024	Dec. 31, 2022
Debt [Line Items]
Regulatory assets		$ 15,963		$ 15,963			$ 16,443
Initial shareholder contribution				2,000
Regulatory liabilities		18,518		18,518			17,630
SB 901 securitization charges, net		289	$ 40	562	$ 40
SB 901 Securitization
Debt [Line Items]
Regulatory liabilities		6,127	5,540	6,127	5,540		5,800
SB 901 Securitization | Secured Debt
Debt [Line Items]
Initial shareholder contribution			2,000				1,000
Additional contributions funded by tax benefits				7,590
SB 901 securitization charges, net		289		562
SB 901 Securitization | Secured Debt | Forecast
Debt [Line Items]
Initial shareholder contribution						$ 1,000
SB 901 securitization charges, net	$ 2,090
Nothern California Wild Fire
Debt [Line Items]
Loss contingency, costs incurred			7,500
SB 901 Securitization
Debt [Line Items]
Regulatory assets		5,296	$ 5,500	5,296	$ 5,500		$ 5,378
SB 901 Securitization | SB 901 Securitization
Debt [Line Items]
Amortization of regulatory asset and liability		$ 71		$ 158

SB 901 SECURITIZATION AND CUS_4

SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST (Financial Statement Impact) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Dec. 31, 2022
Debt [Line Items]
Regulatory assets	$ 15,963	$ 16,443
Ending balance	15,963
Balance at December 31, 2022	(17,630)
Ending balance	(18,518)
SB 901 Securitization Inception
Debt [Line Items]
Balance at December 31, 2022	(5,800)
Amortization	240
Additions	(567)
Ending balance	(6,127)
SB 901 Securitization Inception | Customer credit trust
Debt [Line Items]
Additions	(5)
SB 901 Securitization Inception
Debt [Line Items]
Regulatory assets	5,296	$ 5,378
Amortization	(82)
Ending balance	$ 5,296

EQUITY (Narrative) (Details)

EQUITY (Narrative) (Details) - USD ($) $ in Millions

1 Months Ended

3 Months Ended

6 Months Ended

12 Months Ended

24 Months Ended

Aug. 15, 2023

Jul. 19, 2023

Jul. 12, 2023

Jun. 21, 2023

May 15, 2023

Feb. 28, 2023

Feb. 15, 2023

Jul. 19, 2023

Sep. 30, 2023

Jun. 30, 2023

Mar. 31, 2023

Jun. 30, 2022

Mar. 31, 2022

Jun. 30, 2023

Jun. 30, 2022

Dec. 31, 2020

Jun. 30, 2023

Dec. 31, 2022

Jul. 08, 2021

Schedule Of Changes In Equity [Line Items]

Common stock issued, net

$ (609)

$ (610)

$ (609)

$ (407)

Shares outstanding (in shares)

2,568,984,928

2,568,984,928

Common stock, shares outstanding (in shares)

2,062,781,659

2,062,781,659

2,062,781,659

1,987,784,948

Non-GAAP core earnings threshold

$ 6,200

Pacific Gas & Electric Co (Utility)

Schedule Of Changes In Equity [Line Items]

Common stock, shares outstanding (in shares)

120,000,000

120,000,000

120,000,000

Pacific Gas & Electric Co (Utility)

Schedule Of Changes In Equity [Line Items]

Shares outstanding (in shares)

264,374,809

264,374,809

Common stock, shares outstanding (in shares)

264,374,809

264,374,809

264,374,809

264,374,809

Common stock dividends paid

$ 450

$ 3.5

$ 425

$ 3.5

$ 875

$ 425

Pacific Gas & Electric Co (Utility) | Subsequent Event

Schedule Of Changes In Equity [Line Items]

Common stock dividends paid

$ 3.5

Fire Victim Trust

Schedule Of Changes In Equity [Line Items]

Shares sold, tax impact

527

$ 1,400

Number of shares sold (in shares)

350,000,000

Fire Victim Trust | Subsequent Event

Schedule Of Changes In Equity [Line Items]

Number of shares sold (in shares)

410,000,000

60,000,000

Number of shares owned (in shares)

67,743,590

PG&E Corporation

Schedule Of Changes In Equity [Line Items]

Common stock to be received, value

$ 1,300

$ 1,300

$ 1,300

PG&E Corporation | Equity Units

Schedule Of Changes In Equity [Line Items]

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

8,000,000

16,000,000

PG&E Corporation | Equity Units | Forecast

Schedule Of Changes In Equity [Line Items]

Units expected to convert (in shares)

42,000,000

PG&E Corporation | Common Stock

Schedule Of Changes In Equity [Line Items]

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

67,000,000

Common stock issued, net

$ 634

PG&E Corporation | Subsequent Event

Schedule Of Changes In Equity [Line Items]

Common stock, shares outstanding, adjusted (in shares)

2,023,497,748

2,023,497,748

PG&E Corporation | Subsequent Event | Equity Units

Schedule Of Changes In Equity [Line Items]

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

3,000,000

PG&E Corporation | Subsequent Event | Common Stock

Schedule Of Changes In Equity [Line Items]

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

28,000,000

Common stock issued, net

$ 270

PG&E Corporation | Minimum

Schedule Of Changes In Equity [Line Items]

Percentage of equity security ownership with board of director approval

4.75%

4.75%

4.75%

4.75%

PG&E Corporation | Minimum | Common Stock

Schedule Of Changes In Equity [Line Items]

Amount of shares, right to receive

137,000,000

PG&E Corporation | Minimum | Subsequent Event

Schedule Of Changes In Equity [Line Items]

Percentage of equity security ownership with board of director approval

3.74%

3.74%

PG&E Corporation | Maximum | Common Stock

Schedule Of Changes In Equity [Line Items]

Amount of shares, right to receive

168,000,000

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	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Earnings Per Share [Abstract]
Income (loss) available for common shareholders	$ 406	$ 356	$ 975	$ 831
Weighted average common shares outstanding, basic (in shares)	2,019	1,987	2,005	1,987
Add incremental shares from assumed conversions:
Employee share-based compensation (in shares)	6	8	6	8
Equity Units (in shares)	114	146	126	146
Weighted average common share outstanding, diluted (in shares)	2,139	2,141	2,137	2,141
Total earnings (loss) per common share, diluted (in dollars per share)	$ 0.19	$ 0.17	$ 0.46	$ 0.39

DERIVATIVES (Narrative) (Detail

DERIVATIVES (Narrative) (Details)	Jun. 30, 2023	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Asset, Statement of Financial Position [Extensible Enumeration]	Regulatory assets	Regulatory assets

DERIVATIVES (Volumes of Outstan

DERIVATIVES (Volumes of Outstanding Derivative Contracts) (Details)	Jun. 30, 2023 MMBTU MWh	Dec. 31, 2022 MWh MMBTU
Forwards, Futures and Swaps | Natural Gas (MMBtus)
Derivative [Line Items]
Contract Volume	246,078,190	171,212,813
Forwards, Futures and Swaps | Electricity (MWh)
Derivative [Line Items]
Contract Volume | MWh	9,389,471	10,814,728
Options | Natural Gas (MMBtus)
Derivative [Line Items]
Contract Volume	44,745,000	27,785,000
Options | Electricity (MWh)
Derivative [Line Items]
Contract Volume	277,200	215,600
Congestion revenue rights | Electricity (MWh)
Derivative [Line Items]
Contract Volume | MWh	180,123,433	205,743,505

DERIVATIVES (Outstanding Deriva

DERIVATIVES (Outstanding Derivative Balances) (Details) - Commodity Contract - Pacific Gas & Electric Co (Utility) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Derivatives And Hedging Activities [Line Items]
Netting	$ 142	$ 715
Netting	0	0
Cash Collateral	48	553
Total Derivative Balance	190	1,268
Current assets – other
Derivatives And Hedging Activities [Line Items]
Netting	147	824
Netting	(11)	(170)
Cash Collateral	31	537
Total Derivative Balance	167	1,191
Other noncurrent assets – other
Derivatives And Hedging Activities [Line Items]
Netting	239	306
Netting	0	0
Cash Collateral	0	0
Total Derivative Balance	239	306
Current liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Balance	(80)	(238)
Netting	11	170
Cash Collateral	16	16
Total Derivative Balance	(53)	(52)
Noncurrent liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Balance	(164)	(177)
Netting	0	0
Cash Collateral	1	0
Total Derivative Balance	$ (163)	$ (177)

FAIR VALUE MEASUREMENTS (Assets

FAIR VALUE MEASUREMENTS (Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Assets:
Price risk management instruments, netting	$ 20	$ 367
Price risk management instruments, assets	406	1,497
TOTAL ASSETS	6,074	7,127
Liabilities:
Price risk management instruments, netting	(28)	(186)
TOTAL LIABILITIES	216	229
Amount primarily related to deferred taxes on appreciation of investment value	654	575
Short-term investments
Assets:
Short-term investments	723	658
Fixed-income securities
Assets:
Short-term investments		49
Nuclear decommissioning trusts
Assets:
Short-term investments	126	117
Global equity securities	2,035	1,845
Fixed-income securities	1,988	1,885
TOTAL ASSETS	4,178	3,872
Customer credit trust
Assets:
Short-term investments	7	19
Global equity securities	148	218
Fixed-income securities	321	508
TOTAL ASSETS	476	745
Rabbi trusts
Assets:
Short-term investments	97	25
Global equity securities	5	5
Fixed-income securities		69
Life insurance contracts	65	64
TOTAL ASSETS	167	163
Long-term disability trust
Assets:
Short-term investments	7	10
TOTAL ASSETS	124	143
Price Risk Derivative, Electricity
Assets:
Price risk management instruments, netting	11	40
Price risk management instruments, assets	369	566
Liabilities:
Price risk management instruments, netting	(26)	(20)
Price risk management instruments, liabilities	209	223
Price Risk Derivative, Gas
Assets:
Price risk management instruments, netting	9	327
Price risk management instruments, assets	37	931
Liabilities:
Price risk management instruments, netting	(2)	(166)
Price risk management instruments, liabilities	7	6
Level 1
Assets:
Price risk management instruments, gross subject to netting	0	0
TOTAL ASSETS	4,428	4,207
Liabilities:
TOTAL LIABILITIES	0	0
Level 1 | Short-term investments
Assets:
Short-term investments	723	658
Level 1 | Fixed-income securities
Assets:
Short-term investments		0
Level 1 | Nuclear decommissioning trusts
Assets:
Short-term investments	126	117
Global equity securities	2,035	1,845
Fixed-income securities	1,195	1,094
TOTAL ASSETS	3,356	3,056
Level 1 | Customer credit trust
Assets:
Short-term investments	7	19
Global equity securities	148	218
Fixed-income securities	85	216
TOTAL ASSETS	240	453
Level 1 | Rabbi trusts
Assets:
Short-term investments	97	25
Global equity securities	5	5
Fixed-income securities		0
Life insurance contracts	0	0
TOTAL ASSETS	102	30
Level 1 | Long-term disability trust
Assets:
Short-term investments	7	10
TOTAL ASSETS	7	10
Level 1 | Price Risk Derivative, Electricity
Assets:
Price risk management instruments, gross subject to netting	0	0
Liabilities:
Price risk management instruments, gross subject to netting	0	0
Level 1 | Price Risk Derivative, Gas
Assets:
Price risk management instruments, gross subject to netting	0	0
Liabilities:
Price risk management instruments, gross subject to netting	0	0
Level 2
Assets:
Price risk management instruments, gross subject to netting	56	698
TOTAL ASSETS	1,150	1,963
Liabilities:
TOTAL LIABILITIES	40	182
Level 2 | Short-term investments
Assets:
Short-term investments	0	0
Level 2 | Fixed-income securities
Assets:
Short-term investments		49
Level 2 | Nuclear decommissioning trusts
Assets:
Short-term investments	0	0
Global equity securities	0	0
Fixed-income securities	793	791
TOTAL ASSETS	793	791
Level 2 | Customer credit trust
Assets:
Short-term investments	0	0
Global equity securities	0	0
Fixed-income securities	236	292
TOTAL ASSETS	236	292
Level 2 | Rabbi trusts
Assets:
Short-term investments	0	0
Global equity securities	0	0
Fixed-income securities		69
Life insurance contracts	65	64
TOTAL ASSETS	65	133
Level 2 | Long-term disability trust
Assets:
Short-term investments	0	0
TOTAL ASSETS	0	0
Level 2 | Price Risk Derivative, Electricity
Assets:
Price risk management instruments, gross subject to netting	28	94
Liabilities:
Price risk management instruments, gross subject to netting	31	10
Level 2 | Price Risk Derivative, Gas
Assets:
Price risk management instruments, gross subject to netting	28	604
Liabilities:
Price risk management instruments, gross subject to netting	9	172
Level 3
Assets:
Price risk management instruments, gross subject to netting	330	432
TOTAL ASSETS	330	432
Liabilities:
TOTAL LIABILITIES	204	233
Level 3 | Short-term investments
Assets:
Short-term investments	0	0
Level 3 | Fixed-income securities
Assets:
Short-term investments		0
Level 3 | Nuclear decommissioning trusts
Assets:
Short-term investments	0	0
Global equity securities	0	0
Fixed-income securities	0	0
TOTAL ASSETS	0	0
Level 3 | Customer credit trust
Assets:
Short-term investments	0	0
Global equity securities	0	0
Fixed-income securities	0	0
TOTAL ASSETS	0	0
Level 3 | Rabbi trusts
Assets:
Short-term investments	0	0
Global equity securities	0	0
Fixed-income securities		0
Life insurance contracts	0	0
TOTAL ASSETS	0	0
Level 3 | Long-term disability trust
Assets:
Short-term investments	0	0
TOTAL ASSETS	0	0
Level 3 | Price Risk Derivative, Electricity
Assets:
Price risk management instruments, gross subject to netting	330	432
Liabilities:
Price risk management instruments, gross subject to netting	204	233
Level 3 | Price Risk Derivative, Gas
Assets:
Price risk management instruments, gross subject to netting	0	0
Liabilities:
Price risk management instruments, gross subject to netting	0	0
Fair Value Measured at Net Asset Value Per Share | Nuclear decommissioning trusts
Assets:
Assets measured at NAV	29	25
Fair Value Measured at Net Asset Value Per Share | Long-term disability trust
Assets:
Assets measured at NAV	$ 117	$ 133

FAIR VALUE MEASUREMENTS (Level

FAIR VALUE MEASUREMENTS (Level 3 Measurements and Sensitivity Analysis) (Details) $ in Millions	Jun. 30, 2023 USD ($) $ / shares	Dec. 31, 2022 USD ($) $ / shares
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets | $	$ 406	$ 1,497
Market approach | Congestion revenue rights
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets | $	272	305
Liabilities | $	121	138
Discounted cash flow | Power purchase agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets | $	58	127
Liabilities | $	$ 83	$ 95
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)	(145.09)	(145.09)
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)	843.59	2,724.93
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)	0.92	0.89
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)	(7.91)	(6.39)
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)	263.13	286.75
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)	64.94	78.14

FAIR VALUE MEASUREMENTS (Leve_2

FAIR VALUE MEASUREMENTS (Level 3 Reconciliation) (Details) - Level 3 - Price risk management instruments - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Asset (Liability) balance, beginning of period	$ 212	$ (24)	$ 199	$ (34)
Included in regulatory assets and liabilities or balancing accounts	(86)	35	(73)	45
Asset balance, end of period	$ 126	$ 11	$ 126	$ 11

FAIR VALUE MEASUREMENTS (Carryi

FAIR VALUE MEASUREMENTS (Carrying Amount and Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Carrying Amount
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	$ 4,430	$ 4,355
Carrying Amount | Pacific Gas & Electric Co (Utility)
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	35,625	32,847
Level 2 | Fair Value
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	4,489	4,490
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	$ 30,473	$ 27,666

FAIR VALUE MEASUREMENTS (Schedu

FAIR VALUE MEASUREMENTS (Schedule of Unrealized Gains Losses Related to Available-for-sale Investments) (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Debt Securities, Available-for-sale [Line Items]
Amount primarily related to deferred taxes on appreciation of investment value	$ 654	$ 575
Nuclear decommissioning trusts
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	2,600	2,521
Total Unrealized Gains	1,698	1,478
Total Unrealized Losses	(120)	(127)
Total Fair Value	4,178	3,872
Nuclear decommissioning trusts | Short-term investments
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	126	117
Total Unrealized Gains	0	0
Total Unrealized Losses	0	0
Total Fair Value	126	117
Nuclear decommissioning trusts | Global equity securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	391	413
Total Unrealized Gains	1,684	1,468
Total Unrealized Losses	(11)	(11)
Total Fair Value	2,064	1,870
Nuclear decommissioning trusts | Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	2,083	1,991
Total Unrealized Gains	14	10
Total Unrealized Losses	(109)	(116)
Total Fair Value	1,988	1,885
Customer credit trust
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	459	754
Total Unrealized Gains	23	13
Total Unrealized Losses	(6)	(22)
Total Fair Value	476	745
Customer credit trust | Short-term investments
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	7	19
Total Unrealized Gains	0	0
Total Unrealized Losses	0	0
Total Fair Value	7	19
Customer credit trust | Global equity securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	129	219
Total Unrealized Gains	23	13
Total Unrealized Losses	(4)	(14)
Total Fair Value	148	218
Customer credit trust | Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	323	516
Total Unrealized Gains	0	0
Total Unrealized Losses	(2)	(8)
Total Fair Value	$ 321	$ 508

FAIR VALUE MEASUREMENTS (Sche_2

FAIR VALUE MEASUREMENTS (Schedule of Maturities on Debt Securities) (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Nuclear decommissioning trusts
Debt Securities, Available-for-sale [Line Items]
Total maturities of fixed-income securities	$ 4,178	$ 3,872
Nuclear decommissioning trusts | Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Less than 1 year	22
1–5 years	627
5–10 years	497
More than 10 years	842
Total maturities of fixed-income securities	1,988	1,885
Customer credit trust
Debt Securities, Available-for-sale [Line Items]
Total maturities of fixed-income securities	476	745
Customer credit trust | Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Less than 1 year	0
1–5 years	88
5–10 years	80
More than 10 years	153
Total maturities of fixed-income securities	$ 321	$ 508

FAIR VALUE MEASUREMENTS (Sche_3

FAIR VALUE MEASUREMENTS (Schedule of Activity for Debt and Equity Securities) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Proceeds from sales and maturities of nuclear decommissioning trust investments			$ 751	$ 1,369
Nuclear decommissioning trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Proceeds from sales and maturities of nuclear decommissioning trust investments	$ 474	$ 948	751	1,369
Gross realized gains on securities	37	81	42	137
Gross realized losses on securities	(10)	(58)	(18)	(65)
Customer credit trust
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Proceeds from sales and maturities of nuclear decommissioning trust investments	135	0	304	0
Gross realized gains on securities	6	1	8	1
Gross realized losses on securities	(5)	$ (8)	$ (10)	$ (8)
Impairment write down	$ 4.3

WILDFIRE-RELATED CONTINGENCIE_2

WILDFIRE-RELATED CONTINGENCIES (2019 Kincade Fire, 2020 Zogg Fire, 2021 Dixie Fire and 2022 Mosquito Fire) (Details) numberOfPeople in Millions, $ in Millions

6 Months Ended

Feb. 21, 2023 USD ($)

Oct. 25, 2022 USD ($)

Mar. 18, 2022 USD ($)

Jan. 05, 2022 USD ($)

Oct. 29, 2021 USD ($) a

Nov. 04, 2019 numberOfPeople

Jun. 30, 2023 USD ($)

Jun. 30, 2022 USD ($)

Jul. 19, 2023 notice numberOfClaimHolder complaint numberOfPlaintiff plaintiff

May 31, 2023 USD ($)

Feb. 24, 2023 notice

Jan. 17, 2023 USD ($)

Dec. 31, 2022 USD ($)

Sep. 06, 2022 a structure injury numberOfFatality

Aug. 31, 2022 USD ($)

Jun. 09, 2022 notice

Apr. 30, 2022 USD ($)

Sep. 24, 2021 misdemeanor felony

Jul. 13, 2021 a structure injury

Sep. 27, 2020 a fatality structure injury

Oct. 23, 2019 a numberOfFatality injury structure

Loss Contingencies [Line Items]

Amount expected to pay

$ 234

$ 235

Settlement amount proposed

$ 24

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

Fire fighting costs recovery requested

$ 90

Potential loss contingency

1,025

Insurance receivable

430

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

Potential loss contingency

400

Insurance receivable

372

Number of criminal complaints (count) | notice

11

31

Number of criminal complaints dismissed (count) | notice

10

20

Stipulation costs payable

$ 50

Penalty recommended

$ 155

Costs unable to recover

$ 140

Litigation liability, payment accrual

10

Fire suppression and other costs

$ 34.5

Liability insurance coverage

611

Initial self-insured retention per occurrence

60

Legal fees

32

2020 Zogg fire | Other Current Liabilities

Loss Contingencies [Line Items]

Stipulation costs payable

50

Zogg Complaint, 2020

Loss Contingencies [Line Items]

Number of felonies (felony) | felony

11

Number of misdemeanors (misdemeanor) | misdemeanor

20

Insurance Coverage for Wildfire Events

Loss Contingencies [Line Items]

Liability insurance coverage

$ 600

$ 340

Initial self-insured retention per occurrence

60

2021 Dixie fire

Loss Contingencies [Line Items]

Number of acres burned (acre) | a

963,309

Number of structures destroyed (structure) | structure

1,311

Number of structures damaged (structure) | structure

94

Insurance receivable

528

Liability insurance coverage

900

Number of residential structures destroyed (structure) | structure

763

Number of multi-family residential structures destroyed (structure) | structure

12

Number of commercial residential structures destroyed (structure) | structure

8

Number of commercial non-residential structures destroyed (structure) | structure

148

Number of detached structures destroyed (structure) | structure

466

Number of first responder injuries (injury) | injury

4

Loss contingency liability

1,175

Loss contingency, costs incurred

$ 650

Probable of recovery

1,231

2022 Mosquito fire

Loss Contingencies [Line Items]

Number of acres burned (acre) | a

76,788

Number of fatalities (fatality) | numberOfFatality

0

Number of injuries | injury

0

Number of structures destroyed (structure) | structure

78

Number of structures damaged (structure) | structure

13

Insurance receivable

54

Liability insurance coverage

733

Number of residential structures destroyed (structure) | structure

44

Number of detached structures destroyed (structure) | structure

40

Loss contingency liability

$ 100

Probable of recovery

114

Percentage of fire contained

100%

Subsequent Event | 2019 Kincade fire

Loss Contingencies [Line Items]

Number of complaints (complaint) | complaint

124

Number of plaintiffs represented by complaints | plaintiff

2,839

Subsequent Event | 2020 Zogg fire

Loss Contingencies [Line Items]

Number of complaints (complaint) | complaint

29

Number of plaintiffs represented by complaints | numberOfPlaintiff

523

Subsequent Event | 2021 Dixie fire

Loss Contingencies [Line Items]

Number of complaints (complaint) | numberOfClaimHolder

143

Number of plaintiffs represented by complaints | numberOfClaimHolder

6,380

Subsequent Event | 2022 Mosquito fire

Loss Contingencies [Line Items]

Number of complaints (complaint) | complaint

6

Number of plaintiffs represented by complaints | notice

236

FERC TO rates | 2021 Dixie fire

Loss Contingencies [Line Items]

Probable of recovery

117

FERC TO rates | 2022 Mosquito fire

Loss Contingencies [Line Items]

Probable of recovery

9

WEMA | 2021 Dixie fire

Loss Contingencies [Line Items]

Probable of recovery

411

Increase in regulatory asset

23

WEMA | 2022 Mosquito fire

Loss Contingencies [Line Items]

Probable of recovery

51

National Park | 2021 Dixie fire

Loss Contingencies [Line Items]

Number of acres burned (acre) | a

70,000

National Forrest | 2021 Dixie fire

Loss Contingencies [Line Items]

Number of acres burned (acre) | a

685,000

California General Fund | 2020 Zogg fire

Loss Contingencies [Line Items]

Amount expected to pay

$ 10

Pacific Gas & Electric Co (Utility)

Loss Contingencies [Line Items]

Amount expected to pay

$ 234

$ 235

WILDFIRE-RELATED CONTINGENCIE_3

WILDFIRE-RELATED CONTINGENCIES (Losses For Claims) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)
2019 Kincade fire
Loss Contingency Accrual [Roll Forward]
Loss accrual, beginning balance	$ 650
Accrued Losses	0
Payments	(192)
Loss accrual, ending balance	458
2020 Zogg fire
Loss Contingency Accrual [Roll Forward]
Loss accrual, beginning balance	32
Accrued Losses	0
Payments	(13)
Loss accrual, ending balance	19
2021 Dixie fire
Loss Contingency Accrual [Roll Forward]
Loss accrual, beginning balance	1,131
Accrued Losses	0
Payments	(447)
Loss accrual, ending balance	$ 684

WILDFIRE-RELATED CONTINGENCIE_4

WILDFIRE-RELATED CONTINGENCIES (Loss Recoveries) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)
2022 Mosquito fire
Loss Contingencies [Line Items]
Probable of recovery	$ 114
2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery	1,231
Insurance | 2022 Mosquito fire
Loss Contingencies [Line Items]
Probable of recovery	54
Insurance | 2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery	528
FERC TO rates | 2022 Mosquito fire
Loss Contingencies [Line Items]
Probable of recovery	9
FERC TO rates | 2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery	117
WEMA | 2022 Mosquito fire
Loss Contingencies [Line Items]
Probable of recovery	51
WEMA | 2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery	411
Wildfire Fund | 2022 Mosquito fire
Loss Contingencies [Line Items]
Probable of recovery	0
Wildfire Fund | 2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery	$ 175

WILDFIRE-RELATED CONTINGENCIE_5

WILDFIRE-RELATED CONTINGENCIES (Insurance Coverage) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Apr. 30, 2023	Aug. 01, 2023	Mar. 31, 2023	Jun. 30, 2023	Aug. 31, 2022	Apr. 30, 2022
Loss Contingencies [Line Items]
Insurance premium costs, recovery, coverage amount				$ 1,400
Insurance Coverage for Wildfire Events
Loss Contingencies [Line Items]
Liability insurance coverage					$ 600	$ 340
Costs for insurance coverage			$ 263
Initial self-insured retention per occurrence				60
Insurance commuted				207
Insurance Coverage for Wildfire Events | Minimum
Loss Contingencies [Line Items]
Liability insurance coverage				757
Insurance Coverage for Wildfire Events | Maximum
Loss Contingencies [Line Items]
Liability insurance coverage				970
Insurance Coverage for Wildfire Events | Forecast
Loss Contingencies [Line Items]
Costs for insurance coverage		$ 516
Insurance Coverage For Non-Wildfire Liabilities
Loss Contingencies [Line Items]
Liability insurance coverage	$ 700
Costs for insurance coverage	167
Initial self-insured retention per occurrence	$ 10
Prepaid insurance				$ 204

WILDFIRE-RELATED CONTINGENCIE_6

WILDFIRE-RELATED CONTINGENCIES (Self-Insurance) (Details) - CPUC $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2024 USD ($)	Dec. 31, 2024 USD ($)	Jun. 30, 2023 USD ($)
Loss Contingencies [Line Items]
Self insurance deductible, percent			0.05
Self insurance deductible maximum			$ 50
Forecast
Loss Contingencies [Line Items]
Self insurance rate	$ 400	$ 1,000

WILDFIRE-RELATED CONTINGENCIE_7

WILDFIRE-RELATED CONTINGENCIES (Insurance Receivable) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	$ 794
Accrued insurance recoveries	8
Reimbursements	(355)
Insurance Receivable, Ending Balance	447
Resolved claims	418
Other Receivables
Insurance Receivable [Roll Forward]
Resolved claims	9
2022 Mosquito fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	45
Accrued insurance recoveries	8
Reimbursements	0
Insurance Receivable, Ending Balance	53
Insurance receivable	54
2021 Dixie fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	530
Accrued insurance recoveries	(1)
Reimbursements	(200)
Insurance Receivable, Ending Balance	329
Insurance receivable	528
2020 Zogg fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	118
Accrued insurance recoveries	1
Reimbursements	(54)
Insurance Receivable, Ending Balance	65
Insurance receivable	372
2019 Kincade fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	101
Accrued insurance recoveries	0
Reimbursements	(101)
Insurance Receivable, Ending Balance	0
Insurance receivable	$ 430

WILDFIRE-RELATED CONTINGENCIE_8

WILDFIRE-RELATED CONTINGENCIES (Regulatory Recovery) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)
2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery	$ 1,231
2021 Dixie fire | FERC TO rates
Loss Contingencies [Line Items]
Probable of recovery	117
2021 Dixie fire | WEMA
Loss Contingencies [Line Items]
Probable of recovery	411
2022 Mosquito fire
Loss Contingencies [Line Items]
Probable of recovery	114
2022 Mosquito fire | FERC TO rates
Loss Contingencies [Line Items]
Probable of recovery	9
2022 Mosquito fire | WEMA
Loss Contingencies [Line Items]
Probable of recovery	$ 51

WILDFIRE-RELATED CONTINGENCIE_9

WILDFIRE-RELATED CONTINGENCIES (Wildfire Fund) (Details) - USD ($) $ in Millions		6 Months Ended
	Aug. 23, 2019	Jun. 30, 2023
Loss Contingencies [Line Items]
Disallowance cap, transmission and distribution 2022 equity rate base		$ 3,700
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
2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery		1,231
2021 Dixie fire | Wildfire Fund
Loss Contingencies [Line Items]
Probable of recovery		$ 175

WILDFIRE-RELATED CONTINGENCI_10

WILDFIRE-RELATED CONTINGENCIES (Wildfire-Related Securities Securities Litigation and Claims in District Court) (Details) - Wildfire-Related Class Action $ in Millions	Jun. 30, 2023 USD ($)	Feb. 22, 2019 notice	Jun. 30, 2018 lawsuit
Loss Contingencies [Line Items]
Loss contingency liability | $	$ 300
Number of lawsuits filed against company (lawsuit, complaint) | lawsuit			2
Number of public offerings of notes with complaints against underwriters (offering) | notice		4
Percentage of common stock owned, Fire Victim Trust if common issues additional shares	22.19%

WILDFIRE-RELATED CONTINGENCI_11

WILDFIRE-RELATED CONTINGENCIES (Indemnification Obligations and D&O Insurance Coverage (Details) - Insurance Coverage Claims $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)
Loss Contingencies [Line Items]
Insurance receivable	$ 272
Payments to trust	117
Remaining insurance receivable	$ 155

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, 2020 count
Loss Contingencies [Line Items]
Number of guilty involuntary manslaughter pleas	84
Number of count related to unlawfully causing a fire (count)	1

OTHER CONTINGENCIES AND COMMI_3

OTHER CONTINGENCIES AND COMMITMENTS (Transmission Owner Rate) (Details) - USD ($) $ in Millions			61 Months Ended
	Mar. 17, 2022	Sep. 21, 2018	Mar. 31, 2022	Jun. 30, 2023
Transmission Owner Rate Case Revenue
Loss Contingencies [Line Items]
Regulatory liabilities				$ 449
Regulatory assets				$ 280
Pacific Gas & Electric Co (Utility)
Loss Contingencies [Line Items]
Increase in regulatory liabilities			$ 62.5
Pacific Gas & Electric Co (Utility) | Electric
Loss Contingencies [Line Items]
Requested return on equity rate	9.26%
Requested return on equity rate, incentive component	0.50%
Actual return on equity rate	9.76%
Requested revenue rate		98.85%

OTHER CONTINGENCIES AND COMMI_4

OTHER CONTINGENCIES AND COMMITMENTS (Other Matters) (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Accrued legal liabilities	$ 78	$ 69

OTHER CONTINGENCIES AND COMMI_5

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

OTHER CONTINGENCIES AND COMMI_6

OTHER CONTINGENCIES AND COMMITMENTS (Tax Matters) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)
Commitments and Contingencies Disclosure [Abstract]
Deductibility in question, repair costs for gas transmission and distribution lines	$ 850
Deductibility in question, customer bill credits	$ 400

OTHER CONTINGENCIES AND COMMI_7

OTHER CONTINGENCIES AND COMMITMENTS (Schedule Environmental Remediation Liability Composed) (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Disclosure Commitments And Contingencies Environmental Remediation Liability Composed [Abstract]
Topock natural gas compressor station	$ 291	$ 284
Hinkley natural gas compressor station	106	110
Former manufactured gas plant sites owned by the Utility or third parties	839	750
Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites	119	112
Fossil fuel-fired generation facilities and sites	25	26
Total environmental remediation liability	$ 1,380	$ 1,282

OTHER CONTINGENCIES AND COMMI_8

OTHER CONTINGENCIES AND COMMITMENTS (Environmental Remediation Contingencies Narrative) (Details) $ in Millions	Jun. 30, 2023 USD ($)
Long-term Purchase Commitment [Line Items]
Amount of environmental loss accrual expected to be recovered	$ 1,140
Topock Site
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 231
Topock Site | Pacific Gas & Electric Co (Utility)
Long-term Purchase Commitment [Line Items]
Remediation cost recovery percentage	90%
Hinkley Natural Gas Compressor Station
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 126
Former Manufactured Gas Plant
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 561
Former Manufactured Gas Plant | Pacific Gas & Electric Co (Utility)
Long-term Purchase Commitment [Line Items]
Remediation cost recovery percentage	90%
Utility Owned Generation Facilities and Third Party Disposal Sites
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 78
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%
Fossil Fuel Fired Generation
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 50

OTHER CONTINGENCIES AND COMMI_9

OTHER CONTINGENCIES AND COMMITMENTS (Nuclear Insurance and Purchase Commitments) (Details)	6 Months Ended
	Jun. 30, 2023 USD ($) nuclear_generating_unit
Long-term Purchase Commitment [Line Items]
Number of nuclear generating units (nuclear generating unit) | nuclear_generating_unit	2
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
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
Non-Nuclear Incident
Long-term Purchase Commitment [Line Items]
Amount of property damage and business interruption coverage provided by NEIL for Diablo Canyon	2,500,000,000
European Mutual Association for Nuclear Insurance
Long-term Purchase Commitment [Line Items]
Full insurance policy limit	200,000,000
Potential premium obligation	5,000,000
Nuclear Electric Insurance Limited
Long-term Purchase Commitment [Line Items]
Potential premium obligation	$ 41,000,000

OTHER CONTINGENCIES AND COMM_10

OTHER CONTINGENCIES AND COMMITMENTS (Purchase Commitments) (Details) $ in Billions	Dec. 31, 2022 USD ($)
Commitments and Contingencies Disclosure [Abstract]
Total purchase commitments	$ 35

OTHER CONTINGENCIES AND COMM_11

OTHER CONTINGENCIES AND COMMITMENTS (Oakland Headquarters Lease) (Details) ft² in Thousands, $ in Millions	Jun. 30, 2025 USD ($)	Jul. 11, 2024 USD ($)	Jul. 11, 2023 USD ($)	Jun. 30, 2023 USD ($) ft²	Dec. 31, 2022 USD ($)	Oct. 23, 2020 USD ($) ft²
Operating Leased Assets [Line Items]
Term of contract						34 years 11 months
Operating lease right of use asset				$ 1,418	$ 1,311
Pacific Gas & Electric Co (Utility)
Operating Leased Assets [Line Items]
Operating lease right of use asset				$ 1,418	$ 1,311
Oakland Headquarters Lease | Pacific Gas & Electric Co (Utility)
Operating Leased Assets [Line Items]
Rentable square feet | ft²				659		910
Lease, option payment letter of credit						$ 75
Lease, security letter of credit						$ 75
Operating lease right of use asset				$ 735
Leasehold improvements				262
Leasehold incentives				178
Operating lease, right-of-use liability				$ 913
Oakland Headquarters Lease | Pacific Gas & Electric Co (Utility) | Forecast
Operating Leased Assets [Line Items]
Purchase price, deposits	$ 506	$ 250
Oakland Headquarters Lease | Pacific Gas & Electric Co (Utility) | Subsequent Event
Operating Leased Assets [Line Items]
Purchase price			$ 906
Purchase price, deposits			$ 150