Pacific Gas & Electric (PCG+A) 10-K21 Feb 242023 FY Annual reportFinancial data

Company Profile

Audit Information

Audit Information	12 Months Ended
Audit Information	Dec. 31, 2023
Audit Information [Abstract]
Auditor Firm ID	34
Auditor Name	DELOITTE & TOUCHE LLP
Auditor Location	San Francisco, California

Cover Page

Cover Page - USD ($) $ in Millions	12 Months Ended
Cover Page - USD ($) $ in Millions	Dec. 31, 2023	Feb. 14, 2024	Jun. 30, 2023
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2023
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	1-12609
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	94-3234914
Entity Address, Address Line One	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 Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Document Financial Statement Error Correction [Flag]	false
Entity Shell Company	false
Entity Bankruptcy Proceedings, Reporting Current	true
Entity Public Float			$ 43,861
Entity Common Stock, Shares Outstanding (in shares)		2,611,366,666
Documents Incorporated by Reference	DOCUMENTS INCORPORATED BY REFERENCE Portions of the documents listed below have been incorporated by reference into the indicated parts of this report, as specified in the responses to the item numbers involved: Designated portions of the Joint Proxy Statement relating to the 2024 Annual Meetings of Shareholders Part III (Items 10, 11, 12, 13 and 14)
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	FY
Entity Registrant Name	PG&E CORP
Entity Central Index Key	0001004980
Pacific Gas & Electric Co (Utility)
Document Type	10-K
Entity File Number	1-2348
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	94-0742640
Entity Address, Address Line One	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 Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Document Financial Statement Error Correction [Flag]	false
Entity Shell Company	false
Entity Bankruptcy Proceedings, Reporting Current	true
Entity Common Stock, Shares Outstanding (in shares)		264,374,809
Documents Incorporated by Reference	DOCUMENTS INCORPORATED BY REFERENCE Portions of the documents listed below have been incorporated by reference into the indicated parts of this report, as specified in the responses to the item numbers involved: Designated portions of the Joint Proxy Statement relating to the 2024 Annual Meetings of Shareholders Part III (Items 10, 11, 12, 13 and 14)
Entity Registrant Name	PACIFIC GAS & ELECTRIC CO
Entity Central Index Key	0000075488
The New York Stock Exchange \| Common stock, no par value
Title of 12(b) Security	Common stock, no par value
Trading Symbol	PCG
Security Exchange Name	NYSE
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
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, 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, 4.80% redeemable
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 4.80% redeemable
Trading Symbol	PCG-PG
Security Exchange Name	NYSEAMER
NYSE American LLC \| First preferred stock, cumulative, par value $25 per share, 4.50% redeemable
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 4.50% redeemable
Trading Symbol	PCG-PH
Security Exchange Name	NYSEAMER
NYSE American LLC \| First preferred stock, cumulative, par value $25 per share, 4.36% series A redeemable
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 4.36% series A redeemable
Trading Symbol	PCG-PI
Security Exchange Name	NYSEAMER

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Operating Revenues
Total operating revenues	$ 24,428	$ 21,680	$ 20,642
Operating Expenses
Total deduction to Operating Expenses	11,924	9,809	10,200
SB 901 securitization charges, net	1,267	608	0
Wildfire-related claims, net of recoveries	64	237	258
Wildfire Fund expense	567	477	517
Depreciation, amortization, and decommissioning	3,738	3,856	3,403
Total operating expenses	21,757	19,843	18,759
Operating Income	2,671	1,837	1,883
Interest income	606	162	20
Interest expense	(2,850)	(1,917)	(1,601)
Other income, net	272	394	457
Reorganization items, net	0	0	(11)
Income Before Income Taxes	699	476	748
Income tax benefit	(1,557)	(1,338)	836
Net Income	2,256	1,814	(88)
Preferred stock dividend requirement of subsidiary	14	14	14
Income Available for Common Shareholders	$ 2,242	$ 1,800	$ (102)
Weighted Average Common Shares Outstanding, Basic (in shares)	2,064	1,987	1,985
Weighted Average Common Shares Outstanding, Diluted (in shares)	2,138	2,132	1,985
Net Income Per Common Share, Basic (in dollars per share)	$ 1.09	$ 0.91	$ (0.05)
Net Income Per Common Share, Diluted (in dollars per share)	$ 1.05	$ 0.84	$ (0.05)
Electric
Operating Revenues
Total operating revenues	$ 17,424	$ 15,060	$ 15,131
Operating Expenses
Cost of electricity and natural gas	2,443	2,756	3,232
Natural gas
Operating Revenues
Total operating revenues	7,004	6,620	5,511
Operating Expenses
Cost of electricity and natural gas	$ 1,754	$ 2,100	$ 1,149

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Statement of Comprehensive Income [Abstract]
Net Income (Loss)	$ 2,256	$ 1,814	$ (88)
Other Comprehensive Income (Loss)
Pension and other postretirement benefit plans obligations (net of taxes of $6, $8, and $3, at respective dates)	(16)	21	7
Net unrealized losses on available-for-sale securities (net of taxes of $3, $3, and $0, respectively)	8	(6)	0
Total other comprehensive income (loss)	(8)	15	7
Comprehensive Income (Loss)	2,248	1,829	(81)
Preferred stock dividend requirement of subsidiary	14	14	14
Comprehensive Income (Loss) Attributable to Common Shareholders	$ 2,234	$ 1,815	$ (95)

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Statement of Comprehensive Income [Abstract]
Pension and other postretirement benefit plans obligations, tax	$ 6	$ 8	$ 3
Net unrealized losses on available for sale securities, tax	$ 3	$ 3	$ 0

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Current Assets
Cash and cash equivalents	$ 635	$ 734
Restricted cash (includes $282 million and $201 million related to VIEs at respective dates)	297	213
Accounts receivable
Customers (net of allowance for doubtful accounts of $445 million and $166 million at respective dates) (includes $1.7 billion and $2.5 billion related to VIEs, net of allowance for doubtful accounts of $445 million and $166 million at respective dates)	2,048	2,645
Accrued unbilled revenue (includes $1.1 billion and $1.2 billion related to VIEs at respective dates)	1,254	1,304
Regulatory balancing accounts	5,660	3,264
Other	1,494	1,624
Regulatory assets	300	296
Inventories
Gas stored underground and fuel oil	65	91
Materials and supplies	805	751
Wildfire Fund asset	450	460
Other	1,375	1,433
Total current assets	14,383	12,815
Property, Plant, and Equipment
Electric	80,345	74,772
Gas	29,830	28,226
Construction work in progress	4,452	4,137
Financing lease ROU asset and other	787	19
Total property, plant, and equipment	115,414	107,154
Accumulated depreciation	(33,093)	(30,946)
Net property, plant, and equipment	82,321	76,208
Other Noncurrent Assets
Regulatory assets	17,189	16,443
Customer credit trust	233	745
Nuclear decommissioning trusts	3,574	3,297
Operating lease ROU asset	598	1,311
Wildfire Fund asset	4,297	4,847
Income taxes receivable	24	9
Other (includes noncurrent accounts receivable of $0 and $17 million related to VIEs, net of noncurrent allowance for doubtful accounts of $0 and $1 million at respective dates)	3,079	2,969
Total other noncurrent assets	28,994	29,621
TOTAL ASSETS	125,698	118,644
Current Liabilities
Short-term borrowings	3,971	2,055
Long-term debt, classified as current (includes $176 million and $168 million related to VIEs at respective dates)	1,376	2,268
Accounts payable
Trade creditors	2,309	2,888
Regulatory balancing accounts	1,669	1,658
Other	851	778
Operating lease liabilities	80	231
Financing lease liabilities	259	0
Interest payable (includes $67 million and $116 million related to VIEs at respective dates)	679	626
Wildfire-related claims	1,422	1,912
Other	4,698	3,372
Total current liabilities	17,314	15,788
Noncurrent Liabilities
Long-term debt (includes $10.5 billion and $10.3 billion related to VIEs at respective dates)	50,975	47,742
Regulatory liabilities	19,444	17,630
Pension and other postretirement benefits	476	231
Asset retirement obligations	5,512	5,912
Deferred income taxes	1,980	2,732
Operating lease liabilities	518	1,243
Financing lease liabilities	554	0
Other	3,633	4,291
Total noncurrent liabilities	83,092	79,781
Shareholders’ Equity
Common stock, no par value, authorized 3,600,000,000 and 3,600,000,000 shares at respective dates; 2,133,597,758 and 1,987,784,948 shares outstanding at respective dates	30,374	32,887
Treasury stock, at cost; 0 and 247,743,590 shares at respective dates	0	(2,517)
Reinvested earnings	(5,321)	(7,542)
Accumulated other comprehensive loss	(13)	(5)
Total shareholders’ equity	25,040	22,823
Noncontrolling Interest - Preferred Stock of Subsidiary	252	252
Total equity	25,292	23,075
TOTAL LIABILITIES AND EQUITY	$ 125,698	$ 118,644

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Restricted cash (includes $282 million and $201 million related to VIEs at respective dates)	$ 297	$ 213
Allowance for doubtful accounts	445	166
Customers (net of allowance for doubtful accounts of $445 million and $166 million at respective dates) (includes $1.7 billion and $2.5 billion related to VIEs, net of allowance for doubtful accounts of $445 million and $166 million at respective dates)	2,048	2,645
Accrued unbilled revenue (includes $1.1 billion and $1.2 billion related to VIEs at respective dates)	1,254	1,304
Long-term debt, classified as current (includes $176 million and $168 million related to VIEs at respective dates)	1,376	2,268
Interest payable (includes $67 million and $116 million related to VIEs at respective dates)	679	626
Long-term debt (includes $10.5 billion and $10.3 billion related to VIEs at respective dates)	$ 50,975	$ 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)	2,133,597,758	1,987,784,948
Treasury stock, shares at cost (in shares)	0	247,743,590
Variable Interest Entity, Primary Beneficiary
Restricted cash (includes $282 million and $201 million related to VIEs at respective dates)	$ 282	$ 201
Allowance for doubtful accounts	445	166
Customers (net of allowance for doubtful accounts of $445 million and $166 million at respective dates) (includes $1.7 billion and $2.5 billion related to VIEs, net of allowance for doubtful accounts of $445 million and $166 million at respective dates)	1,700	2,500
Accrued unbilled revenue (includes $1.1 billion and $1.2 billion related to VIEs at respective dates)	1,100	1,200
Net noncurrent accounts receivable	0	17
Noncurrent allowance for doubtful accounts	0	1
Long-term debt, classified as current (includes $176 million and $168 million related to VIEs at respective dates)	176	168
Interest payable (includes $67 million and $116 million related to VIEs at respective dates)	67	116
Long-term debt (includes $10.5 billion and $10.3 billion related to VIEs at respective dates)	$ 10,500	$ 10,300

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash Flows from Operating Activities
Net Income (Loss)	$ 2,256	$ 1,814	$ (88)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	3,738	3,856	3,403
Bad debt expense	636	143	154
Allowance for equity funds used during construction	(179)	(184)	(133)
Deferred income taxes and tax credits, net	(765)	(452)	1,783
Reorganization items, net	0	0	(73)
Wildfire Fund expense	568	477	517
Disallowed capital expenditures	0	15	0
Other	(116)	517	248
Effect of changes in operating assets and liabilities:
Accounts receivable	(369)	(757)	(589)
Wildfire-related insurance receivable	358	453	(723)
Inventories	(28)	(246)	(32)
Accounts payable	(90)	627	117
Wildfire-related claims	(489)	(810)	472
Other current assets and liabilities	397	17	244
Regulatory assets, liabilities, and balancing accounts, net	(429)	(1,131)	(2,266)
Contributions to Wildfire fund	(193)	(193)	(193)
Other noncurrent assets and liabilities	(548)	(425)	(579)
Net cash provided by operating activities	4,747	3,721	2,262
Cash Flows from Investing Activities
Capital expenditures	(9,714)	(9,584)	(7,689)
Proceeds from sale of SFGO	0	0	749
Proceeds from sales and maturities of nuclear decommissioning trust investments	2,235	3,316	1,678
Purchases of nuclear decommissioning trust investments	(2,252)	(3,208)	(1,702)
Proceeds from sales and maturities of customer credit trust investments	556	250	0
Purchases of customer credit trust investments	0	(1,022)	0
Other	13	34	59
Net cash used in investing activities	(9,162)	(10,214)	(6,905)
Cash Flows from Financing Activities
Borrowings under credit facilities	10,675	10,130	9,730
Repayments under credit facilities	(10,540)	(9,750)	(9,976)
Proceeds from debtor-in-possession credit facility	2,100	0	0
Repayments of debtor-in-possession credit facility	(2,181)	0	0
Credit facilities financing fees	0	0	(9)
Short-term debt financing, net of issuance costs of $0, $0, and $1 at respective dates	0	0	300
Short-term debt matured	0	(300)	(1,450)
Proceeds from issuance of long-term debt, net of premium, discount and issuance costs of $67, $29, and $33 at respective dates	5,483	4,271	4,624
Repayments of long-term debt	(3,075)	(5,968)	(87)
Proceeds from DWR loan, net of performance based incentives earned of $0, $38, and $0 at respective dates	0	312	0
Proceeds from issuance of convertible notes, net of discount and issuance costs of $27, $0, and $0 at respective dates	2,123	0	0
Proceeds from sale of future revenue from transmission tower license sales, net of fees	0	0	370
Other	(17)	53	(29)
Net cash provided by financing activities	4,400	7,133	4,323
Net change in cash, cash equivalents, and restricted cash	(15)	640	(320)
Cash, cash equivalents, and restricted cash at January 1	947	307	627
Cash, cash equivalents, and restricted cash at September 30	932	947	307
Less: Restricted cash and restricted cash equivalents	(297)	(213)	(16)
Cash and cash equivalents at September 30	635	734	291
Cash paid for:
Interest, net of amounts capitalized	(2,286)	(1,607)	(1,404)
Income taxes, net	0	0	99
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	1,105	1,174	1,311
Operating lease liabilities arising from obtaining right-of-use assets	269	529	100
Financing lease liabilities arising from obtaining right-of-use assets	52	0	0
Reclassification of operating lease liabilities to financing lease liabilities	913	0	0
DWR loan forgiveness and performance-based disbursements	214	0	0
Changes to PG&E Corporation common stock and treasury stock in connection with the Share Exchange and Tax Matters Agreement	(2,517)	(2,337)	4,854
Common stock dividends declared but not yet paid	21	0	0
Series 2022-A Recovery Bonds
Cash Flows from Financing Activities
Proceeds from issuance of SB 901 recovery bonds, net of financing fees of $0 and $36 at respective dates	0	972	850
Repayments of recovery bonds	(38)	(18)	0
SB 901 Securitization
Cash Flows from Financing Activities
Proceeds from issuance of SB 901 recovery bonds, net of financing fees of $0 and $36 at respective dates	0	7,464	0
Repayments of recovery bonds	$ (130)	$ (33)	$ 0

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash Flows from Financing Activities
Issuance costs for short-term debt	$ 0	$ 0	$ 1
Premium, discount, and issuance costs on proceeds from long-term debt	67	29	33
Performance based incentives earned	0	38	0
SB 901 Securitization
Cash Flows from Financing Activities
Financing fees	0	36	0
Series 2022-A Recovery Bonds
Cash Flows from Financing Activities
Financing fees	0	11	10
Convertible Notes Due 2027
Cash Flows from Financing Activities
Premium, discount, and issuance costs on proceeds from long-term debt	$ 27	$ 0	$ 0

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY - USD ($) $ in Millions		Total	PG&E ShareCo Common Stock	Total Shareholders' Equity	Common Stock		Treasury Stock	Reinvested Earnings	Accumulated Other Comprehensive Income (Loss)	Non- controlling Interest - Preferred Stock of Subsidiary
Beginning balance (in shares) at Dec. 31, 2020					1,984,678,673
Beginning balance at Dec. 31, 2020		$ 21,253		$ 21,001	$ 30,224		$ 0	$ (9,196)	$ (27)	$ 252
Beginning balance, treasury (in shares) at Dec. 31, 2020							0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss)		(88)		(88)				(88)
Other comprehensive income (loss)		7		7					7
Common stock issued, net (in shares)			477,743,590		721,867	[1]
Common stock issued, net	[1]	4,854		4,854	$ 4,854
Treasury stock acquired (in shares)							477,743,590,000,000
Treasury stock acquired		(4,854)		(4,854)			$ (4,854)
Stock-based compensation amortization		51		51	$ 51
Ending balance (in shares) at Dec. 31, 2021					1,985,400,540
Ending balance at Dec. 31, 2021		21,223		20,971	$ 35,129		$ (4,854)	(9,284)	(20)	252
Ending balance, treasury (in shares) at Dec. 31, 2021							477,743,590,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss)		1,814		1,814				1,814
Other comprehensive income (loss)		15		15					15
Common stock issued, net (in shares)					2,384,408
Common stock issued, net		(2,337)		(2,337)	$ (2,337)
Treasury stock disposition (in shares)							(230,000,000)
Treasury stock disposition		2,337		2,337			$ 2,337
Stock-based compensation amortization		95		95	$ 95
Preferred stock dividend requirement of subsidiary in arrears		(59)		(59)				(59)
Preferred stock dividend requirement of subsidiary		$ (13)		(13)				(13)
Ending balance (in shares) at Dec. 31, 2022		1,987,784,948			1,987,784,948
Ending balance at Dec. 31, 2022		$ 23,075		22,823	$ 32,887		$ (2,517)	(7,542)	(5)	252
Ending balance, treasury (in shares) at Dec. 31, 2022		247,743,590					247,743,590
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss)		$ 2,256		2,256				2,256
Other comprehensive income (loss)		(8)		(8)					(8)
Common stock issued, net (in shares)					145,812,810
Common stock issued, net		(2,517)		(2,517)	$ (2,517)
Treasury stock disposition (in shares)							(247,743,590)
Treasury stock disposition		2,517		2,517			$ 2,517
Stock-based compensation amortization		4		4	$ 4
Common stock dividends declared		(21)		(21)				(21)
Preferred stock dividend requirement of subsidiary		$ (14)		(14)				(14)
Ending balance (in shares) at Dec. 31, 2023		2,133,597,758			2,133,597,758
Ending balance at Dec. 31, 2023		$ 25,292		$ 25,040	$ 30,374		$ 0	$ (5,321)	$ (13)	$ 252
Ending balance, treasury (in shares) at Dec. 31, 2023		0					0

[1]Excludes 477,743,590 shares of common stock owned by the Utility. For more information, see Note 6 of the Notes to the Consolidated Financial Statements in Item 8 of the 2021 Form 10-K .

CONDENSED CONSOLIDATED STATEM_7

CONDENSED CONSOLIDATED STATEMENTS OF INCOME, UTILITY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Operating Revenues
Total operating revenues	$ 24,428	$ 21,680	$ 20,642
Operating Expenses
Operating and maintenance	11,924	9,809	10,200
SB 901 securitization charges, net	1,267	608	0
Wildfire-related claims, net of recoveries	64	237	258
Wildfire Fund expense	567	477	517
Depreciation, amortization, and decommissioning	3,738	3,856	3,403
Total operating expenses	21,757	19,843	18,759
Operating Income	2,671	1,837	1,883
Interest income	606	162	20
Interest expense	(2,850)	(1,917)	(1,601)
Other income, net	272	394	457
Reorganization items, net	0	0	(11)
Income Before Income Taxes	699	476	748
Income tax provision (benefit)	(1,557)	(1,338)	836
Net Income	2,256	1,814	(88)
Preferred stock dividend requirement	14	13
Income Available for Common Shareholders	2,242	1,800	(102)
Pacific Gas & Electric Co (Utility)
Operating Revenues
Total operating revenues	24,428	21,680	20,642
Operating Expenses
Operating and maintenance	11,913	9,725	10,194
SB 901 securitization charges, net	1,267	608	0
Wildfire-related claims, net of recoveries	64	237	258
Wildfire Fund expense	567	477	517
Depreciation, amortization, and decommissioning	3,738	3,856	3,403
Total operating expenses	21,746	19,759	18,753
Operating Income	2,682	1,921	1,889
Interest income	593	162	22
Interest expense	(2,485)	(1,658)	(1,373)
Other income, net	293	595	512
Reorganization items, net	0	0	(12)
Income Before Income Taxes	1,083	1,020	1,038
Income tax provision (benefit)	(1,461)	(1,206)	900
Net Income	2,544	2,226	138
Preferred stock dividend requirement	14	14	14
Income Available for Common Shareholders	2,530	2,212	124
Electric
Operating Revenues
Total operating revenues	17,424	15,060	15,131
Operating Expenses
Cost of electricity and natural gas	2,443	2,756	3,232
Electric \| Pacific Gas & Electric Co (Utility)
Operating Revenues
Total operating revenues	17,424	15,060	15,131
Operating Expenses
Cost of electricity and natural gas	2,443	2,756	3,232
Natural gas
Operating Revenues
Total operating revenues	7,004	6,620	5,511
Operating Expenses
Cost of electricity and natural gas	1,754	2,100	1,149
Natural gas \| Pacific Gas & Electric Co (Utility)
Operating Revenues
Total operating revenues	7,004	6,620	5,511
Operating Expenses
Cost of electricity and natural gas	$ 1,754	$ 2,100	$ 1,149

CONDENSED CONSOLIDATED STATEM_8

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME, UTILITY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Net Income (Loss)	$ 2,256	$ 1,814	$ (88)
Other Comprehensive Income (Loss)
Pension and other postretirement benefit plans obligations (net of taxes of $5, $2, and $1, at respective dates)	(16)	21	7
Net unrealized losses on available-for-sale securities (net of taxes of $4, $3, and $0, respectively)	8	(6)	0
Total other comprehensive income (loss)	(8)	15	7
Comprehensive Income (Loss)	2,248	1,829	(81)
Pacific Gas & Electric Co (Utility)
Net Income (Loss)	2,544	2,226	138
Other Comprehensive Income (Loss)
Pension and other postretirement benefit plans obligations (net of taxes of $5, $2, and $1, at respective dates)	(12)	6	(4)
Net unrealized losses on available-for-sale securities (net of taxes of $4, $3, and $0, respectively)	7	(5)	0
Total other comprehensive income (loss)	(5)	1	(4)
Comprehensive Income (Loss)	$ 2,539	$ 2,227	$ 134

CONDENSED CONSOLIDATED STATEM_9

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Pension and other postretirement benefit plans obligations, tax	$ 6	$ 8	$ 3
Net unrealized losses on available for sale securities, tax	3	3	0
Pacific Gas & Electric Co (Utility)
Pension and other postretirement benefit plans obligations, tax	5	2	1
Net unrealized losses on available for sale securities, tax	$ 4	$ 3	$ 0

CONDENSED CONSOLIDATED BALANC_3

CONDENSED CONSOLIDATED BALANCE SHEETS, UTILITY - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Current Assets
Cash and cash equivalents	$ 635	$ 734
Restricted cash (includes $282 million and $201 million related to VIEs at respective dates)	297	213
Accounts receivable
Customers (net of allowance for doubtful accounts of $445 million and $166 million at respective dates) (includes $1.7 billion and $2.5 billion related to VIEs, net of allowance for doubtful accounts of $445 million and $166 million at respective dates)	2,048	2,645
Accrued unbilled revenue (includes $1.1 billion and $1.2 billion related to VIEs at respective dates)	1,254	1,304
Regulatory balancing accounts	5,660	3,264
Other	1,494	1,624
Regulatory assets	300	296
Inventories
Gas stored underground and fuel oil	65	91
Materials and supplies	805	751
Wildfire Fund asset	450	460
Other	1,375	1,433
Total current assets	14,383	12,815
Property, Plant, and Equipment
Electric	80,345	74,772
Gas	29,830	28,226
Construction work in progress	4,452	4,137
Financing lease ROU asset and other	787	19
Total property, plant, and equipment	115,414	107,154
Accumulated depreciation	(33,093)	(30,946)
Net property, plant, and equipment	82,321	76,208
Other Noncurrent Assets
Regulatory assets	17,189	16,443
Customer credit trust	233	745
Nuclear decommissioning trusts	3,574	3,297
Operating lease ROU asset	598	1,311
Wildfire Fund asset	4,297	4,847
Income taxes receivable	24	9
Other (includes noncurrent accounts receivable of $0 and $17 million related to VIEs, net of noncurrent allowance for doubtful accounts of $0 and $1 million at respective dates)	3,079	2,969
Total other noncurrent assets	28,994	29,621
TOTAL ASSETS	125,698	118,644
Current Liabilities
Short-term borrowings	3,971	2,055
Long-term debt, classified as current (includes $176 million and $168 million related to VIEs at respective dates)	1,376	2,268
Accounts payable
Trade creditors	2,309	2,888
Regulatory balancing accounts	1,669	1,658
Other	851	778
Operating lease liabilities	80	231
Financing lease liabilities	259	0
Interest payable (includes $67 million and $116 million related to VIEs at respective dates)	679	626
Wildfire-related claims	1,422	1,912
Other	4,698	3,372
Total current liabilities	17,314	15,788
Noncurrent Liabilities
Long-term debt (includes $10.5 billion and $10.3 billion related to VIEs at respective dates)	50,975	47,742
Regulatory liabilities	19,444	17,630
Pension and other postretirement benefits	476	231
Asset retirement obligations	5,512	5,912
Deferred income taxes	1,980	2,732
Operating lease liabilities	518	1,243
Financing lease liabilities	554	0
Other	3,633	4,291
Total noncurrent liabilities	83,092	79,781
Shareholders’ Equity
Common stock, $5 par value, authorized 800,000,000 shares; 264,374,809 shares outstanding at respective dates	30,374	32,887
Reinvested earnings	(5,321)	(7,542)
Accumulated other comprehensive loss	(13)	(5)
Total shareholders’ equity	25,040	22,823
TOTAL LIABILITIES AND EQUITY	125,698	118,644
Pacific Gas & Electric Co (Utility)
Current Assets
Cash and cash equivalents	442	609
Restricted cash (includes $282 million and $201 million related to VIEs at respective dates)	294	213
Accounts receivable
Customers (net of allowance for doubtful accounts of $445 million and $166 million at respective dates) (includes $1.7 billion and $2.5 billion related to VIEs, net of allowance for doubtful accounts of $445 million and $166 million at respective dates)	2,048	2,645
Accrued unbilled revenue (includes $1.1 billion and $1.2 billion related to VIEs at respective dates)	1,254	1,304
Regulatory balancing accounts	5,660	3,264
Other	1,495	1,633
Regulatory assets	300	296
Inventories
Gas stored underground and fuel oil	65	91
Materials and supplies	805	751
Wildfire Fund asset	450	460
Other	1,374	1,421
Total current assets	14,187	12,687
Property, Plant, and Equipment
Electric	80,345	74,772
Gas	29,830	28,226
Construction work in progress	4,452	4,137
Financing lease ROU asset and other	787	18
Total property, plant, and equipment	115,414	107,153
Accumulated depreciation	(33,093)	(30,946)
Net property, plant, and equipment	82,321	76,207
Other Noncurrent Assets
Regulatory assets	17,189	16,443
Customer credit trust	233	745
Nuclear decommissioning trusts	3,574	3,297
Operating lease ROU asset	598	1,311
Wildfire Fund asset	4,297	4,847
Income taxes receivable	22	7
Other (includes noncurrent accounts receivable of $0 and $17 million related to VIEs, net of noncurrent allowance for doubtful accounts of $0 and $1 million at respective dates)	2,934	2,834
Total other noncurrent assets	28,847	29,484
TOTAL ASSETS	125,355	118,378
Current Liabilities
Short-term borrowings	3,971	2,055
Long-term debt, classified as current (includes $176 million and $168 million related to VIEs at respective dates)	1,376	2,241
Accounts payable
Trade creditors	2,307	2,886
Regulatory balancing accounts	1,669	1,658
Other	820	747
Operating lease liabilities	80	231
Financing lease liabilities	259	0
Interest payable (includes $67 million and $116 million related to VIEs at respective dates)	621	573
Wildfire-related claims	1,422	1,912
Other	4,391	3,067
Total current liabilities	16,916	15,370
Noncurrent Liabilities
Long-term debt (includes $10.5 billion and $10.3 billion related to VIEs at respective dates)	46,376	43,155
Regulatory liabilities	19,444	17,630
Pension and other postretirement benefits	405	160
Asset retirement obligations	5,512	5,912
Deferred income taxes	2,436	3,090
Operating lease liabilities	518	1,243
Financing lease liabilities	554	0
Other	3,670	4,334
Total noncurrent liabilities	78,915	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	30,570	29,280
Reinvested earnings	(2,613)	(3,368)
Accumulated other comprehensive loss	(13)	(8)
Total shareholders’ equity	29,524	27,484
TOTAL LIABILITIES AND EQUITY	$ 125,355	$ 118,378

CONDENSED CONSOLIDATED BALANC_4

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Restricted cash (includes $282 million and $201 million related to VIEs at respective dates)	$ 297	$ 213
Allowance for doubtful accounts	445	166
Customers (net of allowance for doubtful accounts of $445 million and $166 million at respective dates) (includes $1.7 billion and $2.5 billion related to VIEs, net of allowance for doubtful accounts of $445 million and $166 million at respective dates)	2,048	2,645
Accrued unbilled revenue (includes $1.1 billion and $1.2 billion related to VIEs at respective dates)	1,254	1,304
Long-term debt, classified as current (includes $176 million and $168 million related to VIEs at respective dates)	1,376	2,268
Interest payable (includes $67 million and $116 million related to VIEs at respective dates)	679	626
Long-term debt (includes $10.5 billion and $10.3 billion related to VIEs at respective dates)	$ 50,975	$ 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)	2,133,597,758	1,987,784,948
Pacific Gas & Electric Co (Utility)
Restricted cash (includes $282 million and $201 million related to VIEs at respective dates)	$ 294	$ 213
Allowance for doubtful accounts	445	166
Customers (net of allowance for doubtful accounts of $445 million and $166 million at respective dates) (includes $1.7 billion and $2.5 billion related to VIEs, net of allowance for doubtful accounts of $445 million and $166 million at respective dates)	2,048	2,645
Accrued unbilled revenue (includes $1.1 billion and $1.2 billion related to VIEs at respective dates)	1,254	1,304
Long-term debt, classified as current (includes $176 million and $168 million related to VIEs at respective dates)	1,376	2,241
Interest payable (includes $67 million and $116 million related to VIEs at respective dates)	621	573
Long-term debt (includes $10.5 billion and $10.3 billion related to VIEs at respective dates)	$ 46,376	$ 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 $282 million and $201 million related to VIEs at respective dates)	$ 282	$ 201
Allowance for doubtful accounts	445	166
Customers (net of allowance for doubtful accounts of $445 million and $166 million at respective dates) (includes $1.7 billion and $2.5 billion related to VIEs, net of allowance for doubtful accounts of $445 million and $166 million at respective dates)	1,700	2,500
Accrued unbilled revenue (includes $1.1 billion and $1.2 billion related to VIEs at respective dates)	1,100	1,200
Net noncurrent accounts receivable	0	17
Noncurrent allowance for doubtful accounts	0	1
Long-term debt, classified as current (includes $176 million and $168 million related to VIEs at respective dates)	176	168
Interest payable (includes $67 million and $116 million related to VIEs at respective dates)	67	116
Long-term debt (includes $10.5 billion and $10.3 billion related to VIEs at respective dates)	10,500	10,300
Variable Interest Entity, Primary Beneficiary \| Pacific Gas & Electric Co (Utility)
Restricted cash (includes $282 million and $201 million related to VIEs at respective dates)	282	201
Allowance for doubtful accounts	445	166
Customers (net of allowance for doubtful accounts of $445 million and $166 million at respective dates) (includes $1.7 billion and $2.5 billion related to VIEs, net of allowance for doubtful accounts of $445 million and $166 million at respective dates)	1,700	2,500
Accrued unbilled revenue (includes $1.1 billion and $1.2 billion related to VIEs at respective dates)	1,100	1,200
Net noncurrent accounts receivable	0	17
Noncurrent allowance for doubtful accounts	0	1
Long-term debt, classified as current (includes $176 million and $168 million related to VIEs at respective dates)	176	168
Interest payable (includes $67 million and $116 million related to VIEs at respective dates)	67	116
Long-term debt (includes $10.5 billion and $10.3 billion related to VIEs at respective dates)	$ 10,500	$ 10,300

CONDENSED CONSOLIDATED STATE_10

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS, UTILITY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash Flows from Operating Activities
Net Income (Loss)	$ 2,256	$ 1,814	$ (88)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	3,738	3,856	3,403
Bad debt expense	636	143	154
Allowance for equity funds used during construction	(179)	(184)	(133)
Deferred income taxes and tax credits, net	(765)	(452)	1,783
Reorganization items, net	0	0	(73)
Wildfire Fund expense	568	477	517
Disallowed capital expenditures	0	15	0
Other	(116)	517	248
Effect of changes in operating assets and liabilities:
Accounts receivable	(369)	(757)	(589)
Wildfire-related insurance receivable	358	453	(723)
Inventories	(28)	(246)	(32)
Accounts payable	(90)	627	117
Wildfire-related claims	(489)	(810)	472
Other current assets and liabilities	397	17	244
Regulatory assets, liabilities, and balancing accounts, net	(429)	(1,131)	(2,266)
Contributions to Wildfire fund	(193)	(193)	(193)
Other noncurrent assets and liabilities	(548)	(425)	(579)
Net cash provided by operating activities	4,747	3,721	2,262
Cash Flows from Investing Activities
Capital expenditures	(9,714)	(9,584)	(7,689)
Proceeds from sale of SFGO	0	0	749
Proceeds from sales and maturities of nuclear decommissioning trust investments	2,235	3,316	1,678
Purchases of nuclear decommissioning trust investments	(2,252)	(3,208)	(1,702)
Proceeds from sales and maturities of customer credit trust investments	556	250	0
Purchases of customer credit trust investments	0	(1,022)	0
Other	13	34	59
Net cash used in investing activities	(9,162)	(10,214)	(6,905)
Cash Flows from Financing Activities
Borrowings under credit facilities	10,675	10,130	9,730
Repayments under credit facilities	(10,540)	(9,750)	(9,976)
Proceeds from debtor-in-possession credit facility	2,100	0	0
Credit facilities financing fees	0	0	(9)
Short-term debt financing, net of issuance costs of $0, $0, and $1 at respective dates	0	0	300
Short-term debt matured	0	(300)	(1,450)
Proceeds from issuance of long-term debt, net of premium, discount and issuance costs of $67, $29, and $33 at respective dates	5,483	4,271	4,624
Repayments of long-term debt	(3,075)	(5,968)	(87)
Proceeds from DWR loan, net of performance based incentives earned of $0, $38, and $0 at respective dates	0	312	0
Proceeds from sale of future revenue from transmission tower license sales, net of fees	0	0	370
Other	(17)	53	(29)
Net cash provided by financing activities	4,400	7,133	4,323
Net change in cash, cash equivalents, and restricted cash	(15)	640	(320)
Cash, cash equivalents, and restricted cash at January 1	947	307	627
Cash, cash equivalents, and restricted cash at September 30	932	947	307
Less: Restricted cash and restricted cash equivalents	(297)	(213)	(16)
Cash and cash equivalents at September 30	635	734	291
Supplemental disclosures of cash flow information
Interest, net of amounts capitalized	(2,286)	(1,607)	(1,404)
Income taxes, net	0	0	99
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	1,105	1,174	1,311
Operating lease liabilities arising from obtaining right-of-use assets	269	529	100
Financing lease liabilities arising from obtaining right-of-use assets	52	0	0
Reclassification of operating lease liabilities to financing lease liabilities	913	0	0
DWR loan forgiveness and performance-based disbursements	214	0	0
Series 2022-A Recovery Bonds
Cash Flows from Financing Activities
Proceeds from issuance of SB 901 recovery bonds, net of financing fees of $0 and $36 at respective dates	0	972	850
Repayments of recovery bonds	(38)	(18)	0
SB 901 Securitization
Cash Flows from Financing Activities
Proceeds from issuance of SB 901 recovery bonds, net of financing fees of $0 and $36 at respective dates	0	7,464	0
Repayments of recovery bonds	(130)	(33)	0
Pacific Gas & Electric Co (Utility)
Cash Flows from Operating Activities
Net Income (Loss)	2,544	2,226	138
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	3,738	3,856	3,403
Bad debt expense	636	143	154
Allowance for equity funds used during construction	(179)	(184)	(133)
Deferred income taxes and tax credits, net	(663)	(319)	1,846
Reorganization items, net	0	0	(41)
Wildfire Fund expense	568	477	517
Disallowed capital expenditures	0	15	0
Other	(176)	102	172
Effect of changes in operating assets and liabilities:
Accounts receivable	(361)	(763)	(584)
Wildfire-related insurance receivable	358	453	(723)
Inventories	(28)	(246)	(32)
Accounts payable	(90)	627	44
Wildfire-related claims	(489)	(810)	472
Other current assets and liabilities	402	16	251
Regulatory assets, liabilities, and balancing accounts, net	(429)	(1,131)	(2,266)
Contributions to Wildfire fund	(193)	(193)	(193)
Other noncurrent assets and liabilities	(541)	(438)	(577)
Net cash provided by operating activities	5,097	3,831	2,448
Cash Flows from Investing Activities
Capital expenditures	(9,714)	(9,584)	(7,689)
Proceeds from sale of SFGO	0	0	749
Proceeds from sales and maturities of nuclear decommissioning trust investments	2,235	3,316	1,678
Purchases of nuclear decommissioning trust investments	(2,252)	(3,208)	(1,702)
Proceeds from sales and maturities of customer credit trust investments	556	250	0
Purchases of customer credit trust investments	0	(1,022)	0
Proceeds from (repayments of) intercompany note to PG&E Corporation	0	145	(145)
Other	13	34	59
Net cash used in investing activities	(9,162)	(10,069)	(7,050)
Cash Flows from Financing Activities
Borrowings under credit facilities	10,675	10,130	9,730
Repayments under credit facilities	(10,540)	(9,750)	(9,976)
Proceeds from debtor-in-possession credit facility	2,100	0	0
Credit facilities financing fees	0	0	(9)
Short-term debt financing, net of issuance costs of $0, $0, and $1 at respective dates	0	0	300
Short-term debt matured	0	(300)	(1,450)
Proceeds from issuance of long-term debt, net of premium, discount and issuance costs of $67, $29, and $33 at respective dates	5,483	4,271	4,624
Repayments of long-term debt	(3,075)	(5,941)	(59)
Proceeds from DWR loan, net of performance based incentives earned of $0, $38, and $0 at respective dates	0	312	0
Proceeds from sale of future revenue from transmission tower license sales, net of fees	0	0	370
Preferred stock dividends paid	(14)	(70)	0
Common stock dividends paid	(1,775)	(1,275)	0
Equity contribution from PG&E Corporation	1,290	994	0
Other	3	123	(1)
Net cash provided by financing activities	3,979	6,879	4,379
Net change in cash, cash equivalents, and restricted cash	(86)	641	(223)
Cash, cash equivalents, and restricted cash at January 1	822	181	404
Cash, cash equivalents, and restricted cash at September 30	736	822	181
Less: Restricted cash and restricted cash equivalents	(294)	(213)	(16)
Cash and cash equivalents at September 30	442	609	165
Supplemental disclosures of cash flow information
Interest, net of amounts capitalized	(1,977)	(1,374)	(1,198)
Income taxes, net	0	0	99
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	1,105	1,174	1,311
Operating lease liabilities arising from obtaining right-of-use assets	269	529	100
Financing lease liabilities arising from obtaining right-of-use assets	52	0	0
Reclassification of operating lease liabilities to financing lease liabilities	913	0	0
DWR loan forgiveness and performance-based disbursements	214	0	0
Pacific Gas & Electric Co (Utility) \| Series 2022-A Recovery Bonds
Cash Flows from Financing Activities
Proceeds from issuance of SB 901 recovery bonds, net of financing fees of $0 and $36 at respective dates	0	972	850
Repayments of recovery bonds	(38)	(18)	0
Pacific Gas & Electric Co (Utility) \| SB 901 Securitization
Cash Flows from Financing Activities
Proceeds from issuance of SB 901 recovery bonds, net of financing fees of $0 and $36 at respective dates	0	7,464	0
Repayments of recovery bonds	$ (130)	$ (33)	$ 0

CONDENSED CONSOLIDATED STATE_11

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS, UTILITY (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash Flows from Financing Activities
Issuance costs for short-term debt	$ 0	$ 0	$ 1
Premium, discount, and issuance costs on proceeds from long-term debt	67	29	33
Performance based incentives earned	0	38	0
SB 901 Securitization
Cash Flows from Financing Activities
Financing fees	0	36	0
Series 2022-A Recovery Bonds
Cash Flows from Financing Activities
Financing fees	0	11	10
Pacific Gas & Electric Co (Utility)
Cash Flows from Financing Activities
Issuance costs for short-term debt	0	0	1
Premium, discount, and issuance costs on proceeds from long-term debt	67	29	33
Performance based incentives earned	0	38	0
Pacific Gas & Electric Co (Utility) \| SB 901 Securitization
Cash Flows from Financing Activities
Financing fees		36	0
Pacific Gas & Electric Co (Utility) \| Series 2022-A Recovery Bonds
Cash Flows from Financing Activities
Financing fees	$ 0	$ 11	$ 10

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, 2020	$ 21,253		$ 21,001	$ 25,476	$ 258	$ 30,224	$ 1,322	$ 28,286	$ (9,196)	$ (4,385)	$ (27)	$ (5)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss)	(88)	$ 138	(88)	138					(88)	138
Other comprehensive income (loss)	7	(4)	7	(4)							7	(4)
Ending balance at Dec. 31, 2021	21,223		20,971	25,610	258	35,129	1,322	28,286	(9,284)	(4,247)	(20)	(9)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss)	1,814	2,226	1,814	2,226					1,814	2,226
Other comprehensive income (loss)	15	1	15	1							15	1
Equity contribution				994				994
Preferred stock dividend requirement of subsidiary in arrears	(59)		(59)	(59)					(59)	(59)
Preferred stock dividend requirement				(13)						(13)
Common stock dividend				(1,275)						(1,275)
Ending 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 (Loss)	2,256	2,544	2,256	2,544					2,256	2,544
Other comprehensive income (loss)	(8)	$ (5)	(8)	(5)							(8)	(5)
Equity contribution				1,290				1,290
Preferred stock dividend requirement				(14)						(14)
Common stock dividend	(21)		(21)	(1,775)					(21)	(1,775)
Ending balance at Dec. 31, 2023	$ 25,292		$ 25,040	$ 29,524	$ 258	$ 30,374	$ 1,322	$ 30,570	$ (5,321)	$ (2,613)	$ (13)	$ (13)

ORGANIZATION AND BASIS OF PRESE

ORGANIZATION AND BASIS OF PRESENTATION	12 Months Ended
ORGANIZATION AND BASIS OF PRESENTATION	Dec. 31, 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 is a combined annual report of PG&E Corporation and the Utility. PG&E Corporation’s Consolidated Financial Statements include the accounts of PG&E Corporation, the Utility, and other wholly owned and controlled subsidiaries. The Utility’s Consolidated Financial Statements include the accounts of the Utility and its wholly owned and controlled subsidiaries. All intercompany transactions have been eliminated in consolidation. The Notes to the Consolidated Financial Statements apply to both PG&E Corporation and the Utility. PG&E Corporation and the Utility assess financial performance and allocate resources on a consolidated basis (i.e., the companies operate in one segment). The accompanying Consolidated Financial Statements have been prepared in conformity with GAAP and in accordance with the reporting requirements of Form 10-K. The preparation of financial statements in conformity with GAAP requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Some of the more significant estimates and assumptions relate to the Utility’s regulatory assets and liabilities, wildfire-related liabilities, legal and regulatory contingencies, the Wildfire Fund, environmental remediation liabilities, AROs, wildfire-related receivables, and pension and other post-retirement benefit plan obligations. Management believes that its estimates and assumptions reflected in the Consolidated Financial Statements are appropriate and reasonable. A change in management’s estimates or assumptions could result in an adjustment that would have a material impact on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows during the period in which such change occurred.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	Dec. 31, 2023
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Regulation and Regulated Operations The Utility follows accounting principles for rate-regulated entities and collects rates from customers to recover “revenue requirements” that have been authorized by the CPUC or the FERC based on the Utility’s cost of providing service. The Utility’s ability to recover a significant portion of its authorized revenue requirements through rates is generally independent, or “decoupled,” from the volume of the Utility’s electricity and natural gas sales. The Utility records assets and liabilities that result from the regulated ratemaking process that would not be recorded under GAAP for nonregulated entities. The Utility capitalizes and records as regulatory assets costs that would otherwise be charged to expense if it is probable that the incurred costs will be recovered through future rates. Regulatory assets are amortized over the future periods in which the costs are recovered. If costs expected to be incurred in the future are currently being recovered through rates, the Utility records those expected future costs as regulatory liabilities. Amounts that are probable of being credited or refunded to customers in the future are also recorded as regulatory liabilities. The Utility also records a regulatory balancing account asset or liability for differences between customer billings and authorized revenue requirements that are probable of recovery or refund. In addition, the Utility records a regulatory balancing account asset or liability for differences between incurred costs and customer billings or authorized revenue meant to recover those costs, to the extent that these differences are probable of recovery or refund. These differences have no impact on net income. See “Revenue Recognition” below. Management continues to believe the use of regulatory accounting is applicable and that all regulatory assets and liabilities are recoverable or refundable. To the extent that portions of the Utility’s operations cease to be subject to cost-of-service rate regulation, or recovery is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are written off. Cash, Cash Equivalents, and Restricted Cash Cash and cash equivalents consist of cash and short-term, highly liquid investments with original maturities of three months or less. Cash equivalents are stated at fair value. As of December 31, 2023, the Utility also holds $294 million of restricted cash that primarily consists of AB 1054 and SB 901 fixed recovery charge collections that are to be used to service the associated bonds. Revenue Recognition Revenue from Contracts with Customers The Utility recognizes revenues when electricity and natural gas services are delivered. The Utility records unbilled revenues for the estimated amount of energy delivered to customers but not yet billed at the end of the period. Unbilled revenues are included in Accounts receivable on the Consolidated Balance Sheets. Rates charged to customers are based on CPUC and FERC authorized revenue requirements. Revenues can vary significantly from period to period because of seasonality, weather, and customer usage patterns. Regulatory Balancing Account Revenue The CPUC authorizes most of the Utility’s revenues in the Utility’s GRCs, which occur every four years. 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: Year Ended December 31, (in millions) 2023 2022 2021 Electric Revenue from contracts with customers Residential $ 6,041 $ 6,130 $ 6,089 Commercial 5,643 5,416 5,042 Industrial 1,784 1,626 1,493 Agricultural 1,413 1,830 1,565 Public street and highway lighting 83 77 73 Other, net (1) 136 (247) (84) Total revenue from contracts with customers - electric 15,100 14,832 14,178 Regulatory balancing accounts (2) 2,324 228 953 Total electric operating revenue $ 17,424 $ 15,060 $ 15,131 Natural gas Revenue from contracts with customers Residential $ 3,686 $ 3,353 $ 2,759 Commercial 1,052 1,005 713 Transportation service only 1,603 1,534 1,346 Other, net (1) (145) 163 140 Total revenue from contracts with customers - gas 6,196 6,055 4,958 Regulatory balancing accounts (2) 808 565 553 Total natural gas operating revenue 7,004 6,620 5,511 Total operating revenues $ 24,428 $ 21,680 $ 20,642 (1) This activity is primarily related to the change in unbilled revenue and amounts subject to refund, partially offset by other miscellaneous revenue items. (2) These amounts represent revenues authorized to be billed or refunded to customers. Financial Assets Measured at Amortized Cost – Credit Losses PG&E Corporation and the Utility use the current expected credit loss model to estimate the expected lifetime credit loss on financial assets measured at amortized cost. PG&E Corporation and the Utility evaluate credit risk in their portfolio of financial assets quarterly. As of December 31, 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. Expected credit losses of $636 million, $143 million, and $154 million were recorded in Operating and maintenance expense on the Consolidated Statements of Income for credit losses associated with trade and other receivables during the years ended December 31, 2023, 2022, and 2021, 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 December 31, 2023, the RUBA current balancing accounts receivable balance was $507 million, and CPPMA and FERC noncurrent regulatory asset balances were $5 million and $78 million, respectively. As of December 31, 2022, the RUBA current balancing accounts receivable balance was $126 million, and CPPMA and FERC noncurrent regulatory asset balances were $3 million and $8 million, respectively. Other Receivables and Available-For-Sale Debt Securities Insurance receivables are related to the liability insurance policies PG&E Corporation and the Utility carry. Insurance receivable risk is related to each insurance carrier’s risk of defaulting on their individual policies. Wildfire Fund receivables are the funds available from the statewide fund established under AB 1054 for payment of eligible claims related to the 2021 Dixie fire that exceed $1.0 billion and available insurance coverage. For more information, see Note 14 below. Wildfire Fund receivables risk is related to the Wildfire Fund’s durability, which is a measurement of 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 December 31, 2023, expected credit losses for insurance receivables, Wildfire Fund receivables, and available-for-sale debt securities were immaterial. Emission Allowances The Utility purchases GHG emission allowances to satisfy its compliance obligations. Associated costs are recorded as inventory and included in current assets – other and other noncurrent assets – other on the Consolidated Balance Sheets. Costs are carried at weighted-average and are recoverable through rates. Inventories Inventories are carried at weighted-average cost and include gas stored underground, fuel oil, materials, and supplies. Natural gas stored underground is recorded to inventory when injected and then expensed as the gas is withdrawn for distribution to customers or to be used as fuel for electric generation. Materials and supplies are recorded to inventory when purchased and expensed or capitalized to plant, as appropriate, when consumed or installed. Property, Plant, and Equipment Property, plant, and equipment are reported at the lower of their historical cost less accumulated depreciation or fair value. Historical costs include labor and materials, construction overhead, and AFUDC. See “AFUDC” below. The Utility’s estimated service lives of its property, plant, and equipment were as follows: Estimated Service Balance at December 31, (in millions, except estimated service lives) Lives (years) 2023 2022 Electricity generating facilities (1) 3 to 75 $ 11,423 $ 11,781 Electricity distribution facilities 10 to 70 45,205 41,061 Electricity transmission facilities 15 to 75 17,562 16,413 Natural gas distribution facilities 20 to 60 16,324 15,366 Natural gas transmission and storage facilities 5 to 70 10,496 9,859 General plant and other 5 to 50 9,165 8,518 Financing lease 787 18 Construction work in progress 4,452 4,137 Total property, plant, and equipment 115,414 107,153 Accumulated depreciation (33,093) (30,946) Net property, plant, and equipment (2) $ 82,321 $ 76,207 (1) Balance includes nuclear fuel inventories. Nuclear generating facilities have been authorized by the CPUC to be fully depreciated by December 31, 2025. Stored nuclear fuel inventory is stated at weighted-average cost. Nuclear fuel in the reactor is expensed as it is used based on the amount of energy output. See Note 15 below. (2) Includes $1.7 billion of fire risk mitigation-related property, plant, and equipment securitized in accordance with AB 1054. The Utility depreciates property, plant, and equipment using the composite, or group, method of depreciation, in which a single depreciation rate is applied to the gross investment balance in a particular class of property, with the exception of its securitized property, plant and equipment, which is depreciated over the life of the bond and a pattern consistent with principal payments. This method approximates the straight-line method of depreciation over the useful lives of property, plant, and equipment. The Utility’s composite depreciation rates were 3.56% in 2023, 3.74% in 2022, and 3.82% in 2021. The useful lives of the Utility’s property, plant, and equipment are authorized by the CPUC and the FERC, and the depreciation expense is recovered through rates charged to customers. Depreciation expense includes a component for the original cost of assets and a component for estimated cost of future removal, net of any salvage value at retirement. Upon retirement, the original cost of the retired assets, net of salvage value, is charged against accumulated depreciation. The cost of repairs and maintenance, including planned major maintenance activities and minor replacements of property, is charged to Operating and maintenance expense as incurred. AFUDC AFUDC represents the estimated cost of debt (i.e., interest) and equity funds used to finance regulated plant additions before they go into service and is capitalized as part of the cost of construction. AFUDC is recoverable through rates over the life of the related property once the property is placed in service. AFUDC related to the cost of debt is recorded as a reduction to interest expense. AFUDC related to the cost of equity is recorded in other income. The Utility recorded AFUDC related to debt and equity, respectively, of $82 million and $179 million during 2023, $81 million and $184 million during 2022, and $56 million and $133 million during 2021. Asset Retirement Obligations The following table summarizes the changes in ARO liability during 2023 and 2022, including nuclear decommissioning obligations: (in millions) 2023 2022 ARO liability at beginning of year $ 5,912 $ 5,298 Liabilities incurred — 134 Revision in estimated cash flows (585) 325 Accretion 253 213 Liabilities settled (68) (58) ARO liability at end of year $ 5,512 $ 5,912 PG&E Corporation and the Utility account for an ARO at fair value in the period during which the legal obligation is incurred if a reasonable estimate of fair value and its settlement date can be made. At the time of recording an ARO, the associated asset retirement costs are capitalized as part of the carrying amount of the related long-lived asset. The Utility recognizes a regulatory asset or liability for the timing differences between the recognition of expenses and costs recovered through the ratemaking process. For more information, see Note 3 below. The Utility has not recorded a liability related to certain AROs for assets that are expected to operate in perpetuity. As the Utility cannot estimate a settlement date or range of potential settlement dates for these assets, reasonable estimates of fair value cannot be made. As such, ARO liabilities are not recorded for retirement activities associated with substations, certain hydroelectric facilities; removal of lead-based paint in some facilities and certain communications equipment from leased property; and restoration of land to the conditions under certain agreements. To estimate its liability, the Utility uses a discounted cash flow model based upon significant estimates and assumptions about future decommissioning costs, escalation rates, credit-adjusted risk-free rates, and the estimated date of decommissioning. For generation facilities, the Utility uses a probability-weighted, discounted cash flow model. For nuclear generation facilities, the model also considers multiple decommissioning start-year scenarios. The estimated future cash flows are discounted using a credit-adjusted risk-free rate that reflects the risk associated with the decommissioning obligation. The Utility performs detailed studies of its nuclear generation facilities every three years in conjunction with the NDCTP and updates its nuclear AROs accordingly, unless circumstances warrant more frequent updates, based on its annual evaluation of cost escalation factors and probabilities assigned to various scenarios. The decommissioning cost estimates are based on the plant location and cost characteristics for the Utility’s nuclear power plants. Actual decommissioning costs may vary from these estimates as a result of changes in assumptions such as decommissioning dates; regulatory requirements; technology; and costs of labor, materials, and equipment. The Utility recovers its revenue requirements for decommissioning costs through rates through a non-bypassable charge that the Utility expects will continue until those costs are fully recovered. The ARO liability decreased from $5.9 billion as of December 31, 2022 to $5.5 billion as of December 31, 2023, primarily due to a decrease in nuclear decommissioning and hydroelectric facilities ARO. In the fourth quarter of 2023, the Utility recorded a downward revision to its hydroelectric facilities ARO of $205 million as a result of a revised decommissioning cost estimate. The total nuclear decommissioning obligation was $4.0 billion as of December 31, 2023 compared to $4.1 billion as of December 31, 2022 based on the cost study performed as part of the 2021 NDCTP. As of December 31, 2023, the Utility recorded a $253 million downward adjustment to the nuclear decommissioning ARO to reflect the CPUC’s decision to approve Diablo Canyon’s extended operations until 2030 and the conditional award from the DOE’s Civil Nuclear Credit Program. See “U.S. DOE’s Civil Nuclear Credit Program” below. The Utility’s ARO could be materially impacted if the Utility does not receive the required federal and state licenses, permits, and approvals. Disallowance of Plant Costs PG&E Corporation and the Utility record a charge when it is both probable that costs incurred or projected to be incurred for recently completed plant will not be recoverable through rates charged to customers and the amount of disallowance can be reasonably estimated. Nuclear Decommissioning Trusts The Utility’s nuclear generation facilities consist of two units at Diablo Canyon and the Humboldt Bay independent spent fuel storage installation. Nuclear decommissioning requires the safe removal of a nuclear generation facility from service and the reduction of residual radioactivity to a level that permits termination of the NRC license and release of the property for unrestricted use. The Utility’s nuclear decommissioning costs are recovered through rates and are held in trusts until authorized for release by the CPUC. The Utility classifies its debt investments held in the nuclear decommissioning trusts as available-for-sale. Since the Utility’s nuclear decommissioning trust assets are managed by external investment managers, the Utility does not have the ability to sell its investments at its discretion. Therefore, all unrealized losses are considered other-than-temporary impairments. Gains or losses on the nuclear decommissioning trust investments are refundable to or recoverable from, respectively, customers through rates. Therefore, trust earnings are deferred and included in the regulatory liability for recoveries in excess of the ARO. There is no impact on the Utility’s earnings or accumulated other comprehensive income. The cost of debt and equity securities sold by the trust is determined by specific identification. Government Assistance PG&E Corporation and the Utility received various government assistance programs during the years ended December 31, 2023 and 2022. 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. During the years ended December 31, 2023 and 2022, the Consolidated Statements of Income reflected $56 million and $0 million, respectively, recorded as a deduction to Cost of electricity for income related to government grants for incurred eligible costs to purchase nuclear fuel. 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 or when funds expected to be received from the DOE are less than incurred eligible costs to support the extension of Diablo Canyon, the Utility will recognize those forgiven loans as income related to government grants. The Utility records the income related to government grants as a deduction to expense in the same period(s) that eligible costs are incurred. The following table provides a summary of where the DWR loan activity is presented in PG&E Corporation’s and the Utility’s Consolidated Financial Statements: (in millions) 2023 2022 Long-term debt: DWR Loan Outstanding at January 1 $ 312 $ — Proceeds received (1) — 350 Operating Expenses: Operating and maintenance expense - Performance-based disbursements (124) (38) Operating and maintenance expense - Loan forgiven (90) — Total deduction to Operating Expenses (214) (38) Long-term debt: DWR Loan Outstanding at December 31 $ 98 $ 312 (1) On January 11, 2024, the Utility received $233 million in disbursements from the DWR. U.S. DOE’s Civil Nuclear Credit Program On January 11, 2024, the Utility and DOE entered into a Credit Award and Payment Agreement for up to $1.1 billion related to Diablo Canyon as part of the DOE’s Civil Nuclear Credit Program. The Utility will use these funds to repay its loans outstanding under the DWR Loan Agreement (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 a number of factors, including actual costs incurred to extend the Diablo Canyon operations. 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 and will record a receivable related to government grants. During the year ended December 31, 2023, the Consolidated Statements of Income reflected $76 million and $115 million as deductions to Cost of electricity and 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 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 year ended December 31, 2023 or is expected to be provided in the future that was not previously contractually required. As of December 31, 2023 and December 31, 2022, the SPV had net accounts receivable of $2.7 billion and $3.6 billion, respectively, and outstanding borrowings of $1.5 billion 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 year ended December 31, 2023 or is expected to be provided in the future that was not previously contractually required. On November 12, 2021, PG&E Recovery Funding LLC issued approximately $860 million of Senior Secured Recovery Bonds. On November 30, 2022, PG&E Recovery Funding LLC issued approximately $983 million of Series 2022-A Senior Secured Recovery Bonds. As of December 31, 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 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 year ended December 31, 2023 or is expected to be provided in the future that was not previously contractually required. On May 10, 2022, PG&E Wildfire Recovery Funding LLC issued $3.6 billion aggregate principal amount of senior secured recovery bonds (the “Series 2022-A Recovery Bonds”). On July 20, 2022, PG&E Wildfire Recovery Funding LLC issued $3.9 billion aggregate principal amount of senior secured recovery bonds (the “Series 2022-B Recovery Bonds”). As of December 31, 2023 and December 31, 2022, PG&E Wildfire Recovery Funding LLC had outstanding borrowings of $7.3 billion and $7.5 billion, respectively, included in Long-term debt and Long-term debt, classified as current on the 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 December 31, 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 December 31, 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 the issued letter of credit as well as the amounts it pays for base rent and certain costs, per the office lease agreement. For more information, see “Recognition of Lease Assets and Liabilities” 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 Uti

REGULATORY ASSETS, LIABILITIES,

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	12 Months Ended
REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	Dec. 31, 2023
Regulated Operations [Abstract]
REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	Regulatory Assets Noncurrent regulatory assets are comprised of the following: Balance at December 31, Recovery (in millions) 2023 2022 Pension benefits (1) $ 348 $ 120 Indefinitely Environmental compliance costs 1,218 1,193 32 years Utility retained generation (2) 39 86 4 years Price risk management 160 177 16.5 years Catastrophic event memorandum account (3) 1,074 1,085 1 - 3 years Wildfire expense memorandum account (4) 540 439 TBD years Fire hazard prevention memorandum account (5) 7 79 1 - 2 years Fire risk mitigation memorandum account (6) 110 65 1 - 3 years Wildfire mitigation plan memorandum account (7) 541 756 1 - 3 years Deferred income taxes (8) 3,543 2,730 51 years Insurance premium costs (9) 1 99 2 - 4 years Wildfire mitigation balancing account (10) 120 327 1 - 4 years Vegetation management balancing account (11) 1,538 2,276 1 - 3 years COVID-19 pandemic protection memorandum accounts (12) 17 26 1 - 3 years Microgrid memorandum account (13) 59 213 1 - 3 years Financing costs (14) 196 211 Various SB 901 securitization (15) 5,249 5,378 30 years AROs in excess of recoveries (16) 73 120 Various General rate case memorandum accounts (17) 1,291 — 1 - 2 years Other 1,065 1,063 Various Total noncurrent regulatory assets $ 17,189 $ 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. As of December 31, 2023 and 2022, $43 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 were approved for recovery in the 2020 WMCE final decision. (6) Includes incremental costs associated with fire risk mitigation not included in the WMP’s. Recovery of costs incurred during the period from 2020 through 2022 was requested in the 2023 WGSC application, and costs incurred in 2023 will be requested in a future application. Recovery of FRMMA costs is subject to CPUC review and approval. (7) Includes costs incurred in 2020 through 2023 and associated with each year’s respective approved WMP. Recovery of costs incurred during the period from 2020 through 2022 was requested in the 2023 WGSC application, and costs incurred in 2023 will be requested in a future application. Also includes the noncurrent portion of costs associated with the 2019 WMP that were approved for recovery in 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, respectively. (10) Represents costs associated with certain wildfire mitigation activities for the period of January 1, 2020 through December 31, 2022 . The noncurrent balance includes costs incurred during the 12-month period ending December 31, 2020 that were approved for recovery in the 2021 WMCE final decision. The remaining balance includes costs above 115% of adopted revenue requirements, as authorized in the 2020 GRC rate case, 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 December 31, 2022. The noncurrent balance represents costs above 120% of adopted revenue requirements, as authorized in the 2020 GRC rate case, 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 December 31, 2023, the Utility had recorded uncollectibles in the amount of $5 million for small business customers. The remaining $12 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 residential customers pending approval for recovery in the RUBA in addition to uncollectibles recorded 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, Regulated Operations more than twelve months from the current date. These costs and their amortization periods 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 will be 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 11 below. Recovery periods for this balance vary because the different sites and assets to which the ARO expenses are attributable have different recovery periods. (17) The GRC memorandum accounts record the difference between the gas and electric revenue requirements in effect on January 1, 2023 and through the date of the final 2023 GRC decision as authorized by the CPUC in December 2023. These amounts will be recovered in rates over 24 months, beginning January 1, 2024. In general, regulatory assets represent the cumulative differences between amounts recognized for ratemaking purposes and expense or accumulated other comprehensive income (loss) recognized in accordance with GAAP. Additionally, the Utility does not earn a return on regulatory assets if the related costs do not accrue interest. Accordingly, the Utility earns a return on its regulatory assets for retained generation, and regulatory assets for unamortized loss, net of gain, on reacquired debt. Regulatory Liabilities Current Regulatory Liabilities At December 31, 2023 and 2022, the Utility had current regulatory liabilities of $1.2 billion and $1.1 billion, respectively. At December 31, 2023, current regulatory liabilities consisted primarily of billed revenues exceeding TO20 transmission revenue requirements . Current regulatory liabilities are included within current liabilities-other in the Consolidated Balance Sheets. Noncurrent Regulatory Liabilities Noncurrent regulatory liabilities are comprised of the following: Balance at December 31, (in millions) 2023 2022 Cost of removal obligations (1) $ 8,191 $ 7,773 Public purpose programs (2) 1,238 1,062 Employee benefit plans (3) 1,032 904 Transmission tower wireless licenses (4) 384 430 SFGO sale (5) 185 264 SB 901 securitization (6) 6,628 5,800 Wildfire self-insurance (7) 407 — Other 1,379 1,397 Total noncurrent regulatory liabilities $ 19,444 $ 17,630 (1) Represents the cumulative differences between the recorded costs to remove assets and amounts collected through 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 through 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. Of the $384 million, $288 million will be refunded to FERC-jurisdictional customers through 2042, and $96 million will be refunded to CPUC-jurisdictional customers through 2026. (5) Represents the noncurrent portion of the net gain on the sale of the SFGO, which is being 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. See Note 5 below. (7) Represents amounts collected through rates designated for wildfire self-insurance. See Note 14 below. Regulatory Balancing Accounts The Utility tracks (1) differences between the Utility’s authorized revenue requirement and customer billings, and (2) differences between incurred costs and customer billings. To the extent these differences are probable of recovery or refund over the next 12 months, the Utility records a current regulatory balancing account receivable or payable. Regulatory balancing accounts that the Utility expects to collect or refund over a period exceeding 12 months are recorded as other noncurrent assets – regulatory assets or noncurrent liabilities – regulatory liabilities, respectively, in the Consolidated Balance Sheets. These differences do not have an impact on net income. Balancing accounts fluctuate during the year based on seasonal electric and gas usage and the timing of when costs are incurred and customer revenues are collected. In addition, certain regulatory balancing accounts earn interest which is reflected in Interest income in the Consolidated Statements of Income. Interest income from balancing accounts was $547 million, $153 million and $18 million for the years ended December 31, 2023, 2022, and 2021, respectively. Current regulatory balancing accounts receivable and payable are comprised of the following: Receivable (in millions) 2023 2022 Electric distribution (1) $ 1,092 $ 448 Electric transmission (2) 99 96 Gas distribution and transmission (3) 144 72 Energy procurement (4) 1,002 684 Public purpose programs (5) 137 358 Fire hazard prevention memorandum account (6) 40 — Wildfire mitigation plan memorandum account (7) 161 — Wildfire mitigation balancing account (8) 12 2 Vegetation management balancing account (9) 340 137 Insurance premium costs (10) 227 602 Residential uncollectibles balancing accounts (11) 507 126 Catastrophic event memorandum account (12) 413 144 General rate case memorandum accounts (13) 1,097 — Other 389 595 Total regulatory balancing accounts receivable $ 5,660 $ 3,264 Payable (in millions) 2023 2022 Electric transmission (2) $ 200 $ 228 Gas distribution and transmission (3) 224 66 Energy procurement (4) 77 428 Public purpose programs (5) 299 272 SFGO sale 79 152 Wildfire mitigation balancing account (8) 125 — Nuclear decommissioning adjustment mechanism (14) 216 8 Other 449 504 Total regulatory balancing accounts payable $ 1,669 $ 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 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 which were 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 which were authorized for cost recovery in the 2021 WMCE proceeding and the final decision granting interim rate relief in connection with the 2022 WMCE application. (9) The VMBA tracks routine and enhanced vegetation management activities which were approved for cost recovery in the final decision granting interim rate relief in connection with the 2022 WMCE application. (10) The insurance premium costs accounts 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, respectively. In addition to insurance premium costs recorded in Regulatory balancing accounts receivable and in noncurrent Regulatory assets above, as of December 31, 2023, and 2022 there were $0 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. The RUBA balance increased from December 31, 2022 to December 31, 2023 due to additional under-collections from residential customers, which are expected to be recovered in 2024. (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 which were approved for cost recovery in the 2018 CEMA and 2020 WMCE final decisions. (13) The GRC memorandum accounts track the difference between the revenue requirements in effect on January 1, 2023 and the revenue requirements authorized by the CPUC in the 2023 GRC final decision in December 2023. (14) The Nuclear decommissioning adjustment mechanism (“NDAM”) account tracks the collection of revenue requirements associated with the decommissioning of the Utility’s nuclear facilities which were approved in the 2021 NDCTP final decision. See Note 2 above.

DEBT

DEBT	12 Months Ended
DEBT	Dec. 31, 2023
Debt Disclosure [Abstract]
DEBT	DEBT Credit Facilities and Term Loans The following table summarizes PG&E Corporation’s and the Utility’s outstanding borrowings and availability under their credit facilities at December 31, 2023: (in millions) Termination Maximum Facility Limit Loans Outstanding Letters of Credit Outstanding Facility Utility revolving credit facility June 2028 $ 4,400 (1) $ (1,750) $ (652) $ 1,998 Utility Receivables Securitization Program (2) June 2025 1,499 (3) (1,499) — — (3) PG&E Corporation revolving credit facility June 2026 500 — — 500 Total credit facilities $ 6,399 $ (3,249) $ (652) $ 2,498 (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 alternate base rate plus an applicable margin of 0.375%. On June 9, 2023, the Utility entered into an amendment to the 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. On November 15, 2023, the Utility entered into a Bridge Term Loan Credit Agreement (the “Bridge Term Loan Credit Agreement”), pursuant to which the lenders made available to the Utility term loans in the aggregate principal amount equal to $2.1 billion (the “Term Loans”). The Utility borrowed the entire amount of the Term Loans on November 15, 2023. The Term Loans have a maturity date of August 15, 2024. The Utility is required to prepay loans outstanding under the Bridge Term Loan Credit Agreement, subject to certain exceptions, with 100% of the net cash proceeds received by the Utility from the issuance or incurrence of any debt by its subsidiary, Pacific Generation. Borrowings under the Bridge Term Loan Credit Agreement bear interest based on the Utility’s election of either (1) Term SOFR (as defined in the Bridge Term Loan Credit Agreement) (plus a 0.10% credit spread adjustment) plus an applicable margin of 1.25% or (2) the alternate base rate plus an applicable margin of 0.25%. 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). On December 8, 2023, PG&E Corporation entered into an amendment to its existing term loan agreement to, among other things, extend the maturity date from June 23, 2025 to June 23, 2027, and reduce the applicable margin from 300 basis points to 250 basis points. The term loan bears interest based on Adjusted Term SOFR plus an applicable margin of 2.50%. On December 4, 2023, PG&E Corporation used the net proceeds from the Convertible Notes, together with cash on hand, to prepay $2.15 billion of aggregate principal amount of the term loans under the term loan agreement. See “Convertible Notes” below. In addition, on December 8, 2023, PG&E Corporation used other available funds to prepay $11 million of aggregate principal amount of the term loans under the term loan agreement. As a result of the early extinguishment of these term loans, PG&E Corporation recognized $26 million of unamortized discount and issuance costs in Interest expense in the Consolidated Financial Statements for the year ended December 31, 2023. The outstanding aggregate principal amount of term loans outstanding after giving effect to these prepayments and the amendment to the term loan agreement is $500 million. Long-Term Debt Issuances and Redemptions 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 net 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 6.700% 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. On June 5, 2023, the Utility completed the sale of (i) $850 million aggregate principal amount of 6.100% First Mortgage Bonds due 2029, (ii) $1.15 billion aggregate principal amount of 6.400% First Mortgage Bonds due 2033 and (iii) $500 million aggregate principal amount of 6.750% First Mortgage Bonds due 2053. The net proceeds were used for the repayment of $375 million aggregate principal amount of 3.25% First Mortgage Bonds due June 15, 2023 and for general corporate purposes, including for the repayment of borrowings outstanding under the Utility’s revolving credit facility pursuant to the Utility Revolving Credit Agreement. The Utility used the remaining net proceeds to repay the $500 million aggregate principal amount of 4.25% First Mortgage Bonds due August 1, 2023 at maturity. On November 8, 2023, the Utility completed the sale of $800 million aggregate principal amount of 6.950% First Mortgage Bonds due 2034. The Utility used the net proceeds to repay a portion of the $900 million aggregate principal amount of 1.70% First Mortgage Bonds due November 15, 2023 at maturity. Convertible Notes On December 4, 2023, PG&E Corporation completed the sale of $2.15 billion aggregate principal amount of 4.25% Convertible Senior Secured Notes due December 1, 2027 (the “Convertible Notes”). The Convertible Notes bear interest at an annual rate of 4.25% with interest payable semiannually in arrears on June 1 and December 1 of each year, beginning on June 1, 2024. The net proceeds from these offerings were approximately $2.12 billion, after deducting the Initial Purchasers’ discounts and commissions and PG&E Corporation’s offering expenses. PG&E Corporation used the net proceeds to prepay $2.15 billion outstanding under its term loan agreement. The Convertible Notes are governed by an Indenture (the “Convertible Notes Indenture”) among PG&E Corporation, as the issuer, The Bank of New York Mellon Trust Company, N.A., as Trustee, and JPMorgan Chase Bank, N.A., as collateral agent. The Indenture governing the Convertible Notes contains limited covenants, including those restricting PG&E Corporation’s ability and certain of PG&E Corporation’s subsidiaries’ ability to create liens, engage in sale and leaseback transactions or merge or consolidate with another entity. Prior to the close of business on the business day immediately preceding September 1, 2027, the Convertible Notes will be convertible by means of Combination Settlement (as described below) when the following conditions are met: • during any calendar quarter commencing after the calendar quarter ending on March 31, 2024, if the last reported sale price of PG&E Corporation’s common stock for at least 20 trading days during the period of 30 consecutive trading days ending on, and including the last trading day of the immediately preceding calendar quarter is greater than or equal to 130% of the conversion price on each applicable trading day; • during the five consecutive business day period immediately after any ten consecutive trading day period (“measurement period”) in which the trading price per $1,000 principal amount of Convertible Notes, as determined following a request by a holder of Convertible Notes in accordance with the procedures described in the Convertible Notes Indenture, for each trading day of the measurement period was less than 90% of the product of the last reported sale price of PG&E Corporation’s common stock and the conversion rate on each such trading day; or • upon specified distributions and corporate events described in the Convertible Notes Indenture. On or after September 1, 2027, the Convertible Notes are convertible by means of Combination Settlement (as described below) by holders at any time in whole or in part until the close of business on the business day immediately preceding the maturity date. On December 8, 2023, PG&E Corporation delivered an irrevocable notice (the “Irrevocable Notice”) to the Trustee under the Convertible Notes Indenture to irrevocably fix the Settlement Method upon conversion (as defined in the Convertible Notes Indenture) to Combination Settlement (as defined in the Convertible Notes Indenture) with a Specified Dollar Amount (as defined in the Convertible Notes Indenture) per $1,000 principal amount of Convertible Notes at or above $1,000 for any conversions of the Convertible Notes occurring subsequent to the delivery of such Irrevocable Notice on December 8, 2023; provided that in no event shall the Specified Dollar Amount per $1,000 principal amount of Convertible Notes be less than $1,000. The conversion rate for the Convertible Notes is initially 43.1416 shares of Common Stock per $1,000 principal amount of the Convertible Notes (equivalent to an initial conversion price of approximately $23.18 per share of PG&E Corporation Common Stock). The conversion rate and the corresponding conversion price are subject to adjustment in connection with some events but will not be adjusted for any accrued and unpaid interest. PG&E Corporation may not redeem the Convertible Notes prior to the maturity date. If PG&E Corporation undergoes a Fundamental Change (other than an Exempted Fundamental Change, each as defined in the Convertible Notes Indenture), subject to certain conditions, holders may require PG&E Corporation to repurchase for cash all or any portion of their Convertible Notes at a repurchase price equal to 100% of the principal amount of the Convertible Notes to be repurchased, plus accrued and unpaid interest to, but excluding, the Fundamental Change Repurchase Date (as defined in the Convertible Notes Indenture). As of December 31, 2023, none of the conditions allowing holders of the Convertible Notes to convert had been met. The Convertible Notes are accounted for in accordance with ASC Subtopic 470-20, Debt with Conversion and Other Options . Pursuant to ASC Subtopic 470-20, debt with an embedded conversion feature should be accounted for in its entirety as a liability and no portion of the proceeds from the issuance of the convertible debt instrument should be accounted for as attributable to the conversion feature unless the conversion feature is required to be accounted for separately as an embedded derivative or the conversion feature results in a premium that is subject to the guidance in ASC 470. The Convertible Notes issued are accounted for as a liability with no portion of the proceeds attributable to the conversion options as the conversion feature did not require separate accounting as a derivative, and the Convertible Notes did not involve a premium subject to the guidance in ASC 470. As of December 31, 2023, the Consolidated Financial Statements reflected the net carrying amount of the Convertible Notes of $2.12 billion, with unamortized debt issuance costs of $27 million in Long-term debt. For the year ended December 31, 2023, the Consolidated Statements of Income reflected the total interest expense of approximately $7 million. The following table summarizes PG&E Corporation’s and the Utility’s long-term debt: Balance at (in millions) Contractual Interest Rates December 31, 2023 December 31, 2022 PG&E Corporation Term Loan - Stated Maturity: 2027 (1) variable rate (2) $ 500 $ 2,681 Convertible Notes due 2027 4.25% 2,150 — Senior Secured Notes due 2028 5.00% 1,000 1,000 Senior Secured Notes due 2030 5.25% 1,000 1,000 Less: current portion, net of unamortized discount and debt issuance costs — (28) Unamortized discount and debt issuance costs, net (51) (66) Total PG&E Corporation Long-Term Debt 4,599 4,587 Utility First Mortgage Bonds - Stated Maturity: 2023 1.70% - 4.25% — 2,075 2024 3.40% - 3.75% 800 1,800 2025 3.45% - 4.95% 1,925 1,925 2026 2.95% - 3.15% 2,551 2,551 2027 2.10% - 5.45% 3,000 3,000 2028 3.00% - 4.65% 1,975 1,975 2029 4.20% - 6.10% 1,250 400 2030 4.55% 3,100 3,100 2031 2.50% - 3.25% 3,000 3,000 2032 4.40% - 5.90% 1,050 1,050 2033 6.15% - 6.40% 1,900 — 2034 6.95% 800 — 2040 3.30% - 4.50% 2,951 2,951 2041 4.20% - 4.50% 700 700 2042 3.75% - 4.45% 750 750 2043 4.60% 375 375 2044 4.75% 675 675 2045 4.30% 600 600 2046 4.00% - 4.25% 1,050 1,050 2047 3.95% 850 850 2050 3.50% - 4.95% 5,025 5,025 2052 5.25% 550 550 2053 6.70% - 6.75% 2,000 — Less: current portion, net of unamortized discount and debt issuance costs (800) (2,072) Unamortized discount, premium and debt issuance costs, net (246) (195) Total Utility First Mortgage Bonds 35,831 32,135 Recovery Bonds (3) 9,124 9,292 Less: current portion (176) (168) DWR Loan (4) 98 312 Credit Facilities Receivables Securitization Program - Stated Maturity: 2025 variable rate (5) 1,499 1,184 2-Year Term Loan - Stated Maturity: 2024 variable rate (6) 400 400 Less: current portion (400) — Total Utility Long-Term Debt 46,376 43,155 Total PG&E Corporation Consolidated Long-Term Debt $ 50,975 $ 47,742 (1) On December 8, 2023, PG&E Corporation amended its existing term loan agreement to, among other things, extend the maturity date from June 23, 2025 to June 23, 2027. (2) At December 31, 2023, the contractual London Interbank Offered Rate (“LIBOR”)-based interest rate on the term loan was 7.85% and at December 31, 2022, the contractual Secured Overnight Financing Rate (“SOFR”)-based interest rate on the term loan was 7.44%. (3) The amount includes bonds related to AB 1054 and SB 901 securitization transactions. For AB 1054 interest rates, see the 2021 Form 10-K and 2022 Form 10-K. For SB 901 interest rates, see the 2022 Form 10-K. (4) The Utility is not required to pay interest on the DWR loan, see Note 2 - Government Assistance. (5) At December 31, 2023 and 2022, the contractual SOFR-based interest rate on the Receivables Securitization Program was 6.75% and 5.10%, respectively. (6) At December 31, 2023 and 2022, the contractual SOFR-based interest rate on the term loan was 6.60% and 5.71%, respectively. Contractual Repayment Schedule PG&E Corporation’s and the Utility’s combined stated long-term debt principal repayment amounts at December 31, 2023 are reflected in the table below: (in millions, except interest rates) 2024 2025 2026 2027 2028 Thereafter Total PG&E Corporation Average fixed interest rate — % — % — % 4.25 % 5.00 % 5.25 % 4.67 % Fixed rate obligations $ — $ — $ — $ 2,150 $ 1,000 $ 1,000 $ 4,150 Variable interest rate as of December 31, 2023 — % — % — % 7.85 % — % — % 7.85 % Variable rate obligations $ — $ — $ — $ 500 $ — $ — $ 500 Utility (1) Average fixed interest rate 3.60 % 3.82 % 3.10 % 3.22 % 3.58 % 4.66 % 4.31 % Fixed rate obligations $ 800 $ 1,925 $ 2,551 $ 3,000 $ 1,975 $ 26,626 $ 36,877 Variable interest rate as of December 31, 2023 6.60 % 6.75 % — % — % — % — % 6.72 % Variable rate obligations $ 400 $ 1,499 $ — $ — $ — $ — $ 1,899 Recovery Bonds (2) AB 1054 obligations $ 46 $ 48 $ 50 $ 51 $ 53 $ 1,539 $ 1,787 SB 901 obligations 130 135 141 146 152 6,634 7,338 Total consolidated debt $ 1,376 $ 3,607 $ 2,742 $ 5,847 $ 3,180 $ 35,799 $ 52,551 (1) The balance excludes DWR loan, see Note 2 - Government Assistance. (2) Recovery bonds were issued by, and are repayment obligations of, consolidated VIEs. For AB 1054 interest rates, see the 2021 Form 10-K and 2022 Form 10-K. For SB 901 interest rates, see the 2022 Form 10-K. 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 CHT 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 11 below). The fixed recovery charges and customer credits are presented on a net basis in Operating revenues in the Consolidated Statements of Income and had no net impact on Operating revenues for the year ended December 31, 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 sold PG&E Corporation common stock shares it held, the SB 901 securitization regulatory liability increased accordingly. As tax benefits are monetized, contributions will be made to the customer credit trust, up to $7.59 billion. 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 year ended December 31, 2023, the Utility recorded SB 901 securitization charges, net, of $1.3 billion 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 $322 million for amortization of the regulatory asset and liability in the Consolidated Statements of Income. During the year ended December 31, 2022, the Utility recorded SB 901 securitization charges, net, of $608 million for inception of the regulatory asset and liability as well as tax benefits realized within income tax expense related to the Fire Victim Trust’s sale of PG&E Corporation common stock and amortization of the regulatory asset and liability in the Consolidated Statements of Income. 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 (129) Balance at December 31, 2023 $ 5,249 SB 901 securitization regulatory liability (in millions) Balance at December 31, 2022 $ (5,800) Amortization 451 Additions (1) (1,279) Balance at December 31, 2023 $ (6,628) (1) Includes $12 million of expected returns on investments in the customer credit trust to be credited to customers.

SB 901 SECURITIZATION AND CUSTO

SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST	12 Months Ended
SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST	Dec. 31, 2023
Debt Disclosure [Abstract]
SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST	DEBT Credit Facilities and Term Loans The following table summarizes PG&E Corporation’s and the Utility’s outstanding borrowings and availability under their credit facilities at December 31, 2023: (in millions) Termination Maximum Facility Limit Loans Outstanding Letters of Credit Outstanding Facility Utility revolving credit facility June 2028 $ 4,400 (1) $ (1,750) $ (652) $ 1,998 Utility Receivables Securitization Program (2) June 2025 1,499 (3) (1,499) — — (3) PG&E Corporation revolving credit facility June 2026 500 — — 500 Total credit facilities $ 6,399 $ (3,249) $ (652) $ 2,498 (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 alternate base rate plus an applicable margin of 0.375%. On June 9, 2023, the Utility entered into an amendment to the 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. On November 15, 2023, the Utility entered into a Bridge Term Loan Credit Agreement (the “Bridge Term Loan Credit Agreement”), pursuant to which the lenders made available to the Utility term loans in the aggregate principal amount equal to $2.1 billion (the “Term Loans”). The Utility borrowed the entire amount of the Term Loans on November 15, 2023. The Term Loans have a maturity date of August 15, 2024. The Utility is required to prepay loans outstanding under the Bridge Term Loan Credit Agreement, subject to certain exceptions, with 100% of the net cash proceeds received by the Utility from the issuance or incurrence of any debt by its subsidiary, Pacific Generation. Borrowings under the Bridge Term Loan Credit Agreement bear interest based on the Utility’s election of either (1) Term SOFR (as defined in the Bridge Term Loan Credit Agreement) (plus a 0.10% credit spread adjustment) plus an applicable margin of 1.25% or (2) the alternate base rate plus an applicable margin of 0.25%. 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). On December 8, 2023, PG&E Corporation entered into an amendment to its existing term loan agreement to, among other things, extend the maturity date from June 23, 2025 to June 23, 2027, and reduce the applicable margin from 300 basis points to 250 basis points. The term loan bears interest based on Adjusted Term SOFR plus an applicable margin of 2.50%. On December 4, 2023, PG&E Corporation used the net proceeds from the Convertible Notes, together with cash on hand, to prepay $2.15 billion of aggregate principal amount of the term loans under the term loan agreement. See “Convertible Notes” below. In addition, on December 8, 2023, PG&E Corporation used other available funds to prepay $11 million of aggregate principal amount of the term loans under the term loan agreement. As a result of the early extinguishment of these term loans, PG&E Corporation recognized $26 million of unamortized discount and issuance costs in Interest expense in the Consolidated Financial Statements for the year ended December 31, 2023. The outstanding aggregate principal amount of term loans outstanding after giving effect to these prepayments and the amendment to the term loan agreement is $500 million. Long-Term Debt Issuances and Redemptions 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 net 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 6.700% 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. On June 5, 2023, the Utility completed the sale of (i) $850 million aggregate principal amount of 6.100% First Mortgage Bonds due 2029, (ii) $1.15 billion aggregate principal amount of 6.400% First Mortgage Bonds due 2033 and (iii) $500 million aggregate principal amount of 6.750% First Mortgage Bonds due 2053. The net proceeds were used for the repayment of $375 million aggregate principal amount of 3.25% First Mortgage Bonds due June 15, 2023 and for general corporate purposes, including for the repayment of borrowings outstanding under the Utility’s revolving credit facility pursuant to the Utility Revolving Credit Agreement. The Utility used the remaining net proceeds to repay the $500 million aggregate principal amount of 4.25% First Mortgage Bonds due August 1, 2023 at maturity. On November 8, 2023, the Utility completed the sale of $800 million aggregate principal amount of 6.950% First Mortgage Bonds due 2034. The Utility used the net proceeds to repay a portion of the $900 million aggregate principal amount of 1.70% First Mortgage Bonds due November 15, 2023 at maturity. Convertible Notes On December 4, 2023, PG&E Corporation completed the sale of $2.15 billion aggregate principal amount of 4.25% Convertible Senior Secured Notes due December 1, 2027 (the “Convertible Notes”). The Convertible Notes bear interest at an annual rate of 4.25% with interest payable semiannually in arrears on June 1 and December 1 of each year, beginning on June 1, 2024. The net proceeds from these offerings were approximately $2.12 billion, after deducting the Initial Purchasers’ discounts and commissions and PG&E Corporation’s offering expenses. PG&E Corporation used the net proceeds to prepay $2.15 billion outstanding under its term loan agreement. The Convertible Notes are governed by an Indenture (the “Convertible Notes Indenture”) among PG&E Corporation, as the issuer, The Bank of New York Mellon Trust Company, N.A., as Trustee, and JPMorgan Chase Bank, N.A., as collateral agent. The Indenture governing the Convertible Notes contains limited covenants, including those restricting PG&E Corporation’s ability and certain of PG&E Corporation’s subsidiaries’ ability to create liens, engage in sale and leaseback transactions or merge or consolidate with another entity. Prior to the close of business on the business day immediately preceding September 1, 2027, the Convertible Notes will be convertible by means of Combination Settlement (as described below) when the following conditions are met: • during any calendar quarter commencing after the calendar quarter ending on March 31, 2024, if the last reported sale price of PG&E Corporation’s common stock for at least 20 trading days during the period of 30 consecutive trading days ending on, and including the last trading day of the immediately preceding calendar quarter is greater than or equal to 130% of the conversion price on each applicable trading day; • during the five consecutive business day period immediately after any ten consecutive trading day period (“measurement period”) in which the trading price per $1,000 principal amount of Convertible Notes, as determined following a request by a holder of Convertible Notes in accordance with the procedures described in the Convertible Notes Indenture, for each trading day of the measurement period was less than 90% of the product of the last reported sale price of PG&E Corporation’s common stock and the conversion rate on each such trading day; or • upon specified distributions and corporate events described in the Convertible Notes Indenture. On or after September 1, 2027, the Convertible Notes are convertible by means of Combination Settlement (as described below) by holders at any time in whole or in part until the close of business on the business day immediately preceding the maturity date. On December 8, 2023, PG&E Corporation delivered an irrevocable notice (the “Irrevocable Notice”) to the Trustee under the Convertible Notes Indenture to irrevocably fix the Settlement Method upon conversion (as defined in the Convertible Notes Indenture) to Combination Settlement (as defined in the Convertible Notes Indenture) with a Specified Dollar Amount (as defined in the Convertible Notes Indenture) per $1,000 principal amount of Convertible Notes at or above $1,000 for any conversions of the Convertible Notes occurring subsequent to the delivery of such Irrevocable Notice on December 8, 2023; provided that in no event shall the Specified Dollar Amount per $1,000 principal amount of Convertible Notes be less than $1,000. The conversion rate for the Convertible Notes is initially 43.1416 shares of Common Stock per $1,000 principal amount of the Convertible Notes (equivalent to an initial conversion price of approximately $23.18 per share of PG&E Corporation Common Stock). The conversion rate and the corresponding conversion price are subject to adjustment in connection with some events but will not be adjusted for any accrued and unpaid interest. PG&E Corporation may not redeem the Convertible Notes prior to the maturity date. If PG&E Corporation undergoes a Fundamental Change (other than an Exempted Fundamental Change, each as defined in the Convertible Notes Indenture), subject to certain conditions, holders may require PG&E Corporation to repurchase for cash all or any portion of their Convertible Notes at a repurchase price equal to 100% of the principal amount of the Convertible Notes to be repurchased, plus accrued and unpaid interest to, but excluding, the Fundamental Change Repurchase Date (as defined in the Convertible Notes Indenture). As of December 31, 2023, none of the conditions allowing holders of the Convertible Notes to convert had been met. The Convertible Notes are accounted for in accordance with ASC Subtopic 470-20, Debt with Conversion and Other Options . Pursuant to ASC Subtopic 470-20, debt with an embedded conversion feature should be accounted for in its entirety as a liability and no portion of the proceeds from the issuance of the convertible debt instrument should be accounted for as attributable to the conversion feature unless the conversion feature is required to be accounted for separately as an embedded derivative or the conversion feature results in a premium that is subject to the guidance in ASC 470. The Convertible Notes issued are accounted for as a liability with no portion of the proceeds attributable to the conversion options as the conversion feature did not require separate accounting as a derivative, and the Convertible Notes did not involve a premium subject to the guidance in ASC 470. As of December 31, 2023, the Consolidated Financial Statements reflected the net carrying amount of the Convertible Notes of $2.12 billion, with unamortized debt issuance costs of $27 million in Long-term debt. For the year ended December 31, 2023, the Consolidated Statements of Income reflected the total interest expense of approximately $7 million. The following table summarizes PG&E Corporation’s and the Utility’s long-term debt: Balance at (in millions) Contractual Interest Rates December 31, 2023 December 31, 2022 PG&E Corporation Term Loan - Stated Maturity: 2027 (1) variable rate (2) $ 500 $ 2,681 Convertible Notes due 2027 4.25% 2,150 — Senior Secured Notes due 2028 5.00% 1,000 1,000 Senior Secured Notes due 2030 5.25% 1,000 1,000 Less: current portion, net of unamortized discount and debt issuance costs — (28) Unamortized discount and debt issuance costs, net (51) (66) Total PG&E Corporation Long-Term Debt 4,599 4,587 Utility First Mortgage Bonds - Stated Maturity: 2023 1.70% - 4.25% — 2,075 2024 3.40% - 3.75% 800 1,800 2025 3.45% - 4.95% 1,925 1,925 2026 2.95% - 3.15% 2,551 2,551 2027 2.10% - 5.45% 3,000 3,000 2028 3.00% - 4.65% 1,975 1,975 2029 4.20% - 6.10% 1,250 400 2030 4.55% 3,100 3,100 2031 2.50% - 3.25% 3,000 3,000 2032 4.40% - 5.90% 1,050 1,050 2033 6.15% - 6.40% 1,900 — 2034 6.95% 800 — 2040 3.30% - 4.50% 2,951 2,951 2041 4.20% - 4.50% 700 700 2042 3.75% - 4.45% 750 750 2043 4.60% 375 375 2044 4.75% 675 675 2045 4.30% 600 600 2046 4.00% - 4.25% 1,050 1,050 2047 3.95% 850 850 2050 3.50% - 4.95% 5,025 5,025 2052 5.25% 550 550 2053 6.70% - 6.75% 2,000 — Less: current portion, net of unamortized discount and debt issuance costs (800) (2,072) Unamortized discount, premium and debt issuance costs, net (246) (195) Total Utility First Mortgage Bonds 35,831 32,135 Recovery Bonds (3) 9,124 9,292 Less: current portion (176) (168) DWR Loan (4) 98 312 Credit Facilities Receivables Securitization Program - Stated Maturity: 2025 variable rate (5) 1,499 1,184 2-Year Term Loan - Stated Maturity: 2024 variable rate (6) 400 400 Less: current portion (400) — Total Utility Long-Term Debt 46,376 43,155 Total PG&E Corporation Consolidated Long-Term Debt $ 50,975 $ 47,742 (1) On December 8, 2023, PG&E Corporation amended its existing term loan agreement to, among other things, extend the maturity date from June 23, 2025 to June 23, 2027. (2) At December 31, 2023, the contractual London Interbank Offered Rate (“LIBOR”)-based interest rate on the term loan was 7.85% and at December 31, 2022, the contractual Secured Overnight Financing Rate (“SOFR”)-based interest rate on the term loan was 7.44%. (3) The amount includes bonds related to AB 1054 and SB 901 securitization transactions. For AB 1054 interest rates, see the 2021 Form 10-K and 2022 Form 10-K. For SB 901 interest rates, see the 2022 Form 10-K. (4) The Utility is not required to pay interest on the DWR loan, see Note 2 - Government Assistance. (5) At December 31, 2023 and 2022, the contractual SOFR-based interest rate on the Receivables Securitization Program was 6.75% and 5.10%, respectively. (6) At December 31, 2023 and 2022, the contractual SOFR-based interest rate on the term loan was 6.60% and 5.71%, respectively. Contractual Repayment Schedule PG&E Corporation’s and the Utility’s combined stated long-term debt principal repayment amounts at December 31, 2023 are reflected in the table below: (in millions, except interest rates) 2024 2025 2026 2027 2028 Thereafter Total PG&E Corporation Average fixed interest rate — % — % — % 4.25 % 5.00 % 5.25 % 4.67 % Fixed rate obligations $ — $ — $ — $ 2,150 $ 1,000 $ 1,000 $ 4,150 Variable interest rate as of December 31, 2023 — % — % — % 7.85 % — % — % 7.85 % Variable rate obligations $ — $ — $ — $ 500 $ — $ — $ 500 Utility (1) Average fixed interest rate 3.60 % 3.82 % 3.10 % 3.22 % 3.58 % 4.66 % 4.31 % Fixed rate obligations $ 800 $ 1,925 $ 2,551 $ 3,000 $ 1,975 $ 26,626 $ 36,877 Variable interest rate as of December 31, 2023 6.60 % 6.75 % — % — % — % — % 6.72 % Variable rate obligations $ 400 $ 1,499 $ — $ — $ — $ — $ 1,899 Recovery Bonds (2) AB 1054 obligations $ 46 $ 48 $ 50 $ 51 $ 53 $ 1,539 $ 1,787 SB 901 obligations 130 135 141 146 152 6,634 7,338 Total consolidated debt $ 1,376 $ 3,607 $ 2,742 $ 5,847 $ 3,180 $ 35,799 $ 52,551 (1) The balance excludes DWR loan, see Note 2 - Government Assistance. (2) Recovery bonds were issued by, and are repayment obligations of, consolidated VIEs. For AB 1054 interest rates, see the 2021 Form 10-K and 2022 Form 10-K. For SB 901 interest rates, see the 2022 Form 10-K. 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 CHT 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 11 below). The fixed recovery charges and customer credits are presented on a net basis in Operating revenues in the Consolidated Statements of Income and had no net impact on Operating revenues for the year ended December 31, 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 sold PG&E Corporation common stock shares it held, the SB 901 securitization regulatory liability increased accordingly. As tax benefits are monetized, contributions will be made to the customer credit trust, up to $7.59 billion. 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 year ended December 31, 2023, the Utility recorded SB 901 securitization charges, net, of $1.3 billion 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 $322 million for amortization of the regulatory asset and liability in the Consolidated Statements of Income. During the year ended December 31, 2022, the Utility recorded SB 901 securitization charges, net, of $608 million for inception of the regulatory asset and liability as well as tax benefits realized within income tax expense related to the Fire Victim Trust’s sale of PG&E Corporation common stock and amortization of the regulatory asset and liability in the Consolidated Statements of Income. 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 (129) Balance at December 31, 2023 $ 5,249 SB 901 securitization regulatory liability (in millions) Balance at December 31, 2022 $ (5,800) Amortization 451 Additions (1) (1,279) Balance at December 31, 2023 $ (6,628) (1) Includes $12 million of expected returns on investments in the customer credit trust to be credited to customers.

COMMON STOCK AND SHARE-BASED CO

COMMON STOCK AND SHARE-BASED COMPENSATION	12 Months Ended
COMMON STOCK AND SHARE-BASED COMPENSATION	Dec. 31, 2023
Common Stock And Share-Based Compensation [Abstract]
COMMON STOCK AND SHARE-BASED COMPENSATION	COMMON STOCK AND SHARE-BASED COMPENSATION PG&E Corporation had 2,133,597,758 shares of common stock outstanding at December 31, 2023, which excludes 477,743,590 shares of common stock owned by the Utility. PG&E Corporation held all of the Utility’s outstanding common stock at December 31, 2023. Settlement of Equity Units During 2020, PG&E Corporation issued 16 million PG&E Corporation equity units. The equity units represent the right of the unit holders to receive, on the settlement date, between 137 million and 168 million shares of PG&E Corporation common stock. The common stock received was 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 was subject to certain adjustments as provided therein. The common stock received by these unit holders was originally valued at approximately $1.3 billion and recognized in shareholders’ equity by PG&E Corporation upon the issuance of the equity units. During the year ended December 31, 2023, all equity units were settled, resulting in the issuance of 137 million shares of PG&E Corporation common stock, valued at approximately $1.3 billion. 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 DTAs to offset taxable income). In general, an ownership change occurs if the aggregate stock ownership of certain shareholders (generally five percent shareholders, applying certain look-through and aggregation rules) increases by more than 50% over such shareholders’ lowest percentage ownership during the testing period (generally three years). The Amended Articles limit Transfers (as defined in the Amended Articles) that increase a person’s or entity’s (including certain groups of persons) ownership of PG&E Corporation’s equity securities to 4.75% or more prior to the Restriction Release Date (as defined in the Amended Articles) without approval by the Board of Directors of PG&E Corporation. Shares of PG&E Corporation common stock held directly by the Utility are attributed to PG&E Corporation for income tax purposes and are therefore 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. For example, although PG&E Corporation had 2,611,366,666 shares outstanding as of February 14, 2024, only 2,133,623,076 shares (that is, the number of outstanding shares of common stock less the number of shares held directly by the Utility) count as outstanding for purposes of the ownership restrictions in the Amended Articles. As such, based on the total number of outstanding equity securities, a person’s effective Percentage Stock Ownership limitation for purposes of the Amended Articles as of February 14, 2024 was 3.88% of the outstanding shares. At various dates throughout 2022 and 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 year ended December 31, 2023, the Fire Victim Trust’s sale of PG&E Corporation common stock in the aggregate amount of 247,743,590 shares resulted in an aggregate tax benefit of $1.2 billion recorded in PG&E Corporation’s and the Utility’s Consolidated Financial Statements. Cumulatively through December 31, 2023, the Fire Victim Trust has sold all of its 477,743,590 shares resulting in an aggregate tax benefit of approximately $2.0 billion recorded in PG&E Corporation’s and the Utility’s Consolidated Financial Statements. As of February 14, 2024, the Fire Victim Trust reported having sold all of the shares of PG&E Corporation common stock it had owned and no longer owning any 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 November 27, 2023, the Board of Directors of PG&E Corporation declared a quarterly common stock dividend of $0.01 per share, totaling $21 million, which was paid by January 16, 2024, to holders of record as of December 29, 2023. On February 14, 2024, the Board of Directors of PG&E Corporation declared a quarterly common stock dividend of $0.01 per share, payable on April 15, 2024, to holders of record as of March 28, 2024. Under the Utility’s Articles of Incorporation, the Utility cannot pay common stock dividends unless all cumulative preferred dividends on the Utility’s preferred stock have been paid. Additionally, the CPUC requires the Utility to maintain a capital structure composed of at least 52% equity on average. The CPUC has granted the Utility a temporary waiver from compliance with its authorized capital structure until 2025 for the financing in place upon the Utility’s emergence from Chapter 11. 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. Long-Term Incentive Plans The LTIP (i.e., the PG&E Corporation 2014 LTIP or the PG&E Corporation 2021 LTIP, as applicable) permits various forms of share-based incentive awards, including stock options, restricted stock units, performance shares, and other share-based awards, to eligible employees of PG&E Corporation and its subsidiaries. Non-employee directors of PG&E Corporation are also eligible to receive certain share-based awards. A maximum of 91 million shares of PG&E Corporation common stock (subject to certain adjustments) has been reserved for issuance under the LTIP, of which 61,716,764 shares were available for future awards at December 31, 2023. The following table provides a summary of total share-based compensation expense recognized by PG&E Corporation for share-based incentive awards for 2023: (in millions) 2023 2022 2021 Restricted stock units 64 60 35 Performance shares 27 55 21 Total compensation expense (pre-tax) $ 91 $ 115 $ 56 Total compensation expense (after-tax) $ 65 $ 83 $ 40 Share-based compensation costs are generally not capitalized. There was no material difference between PG&E Corporation and the Utility for the information disclosed above. Stock Options The exercise price of stock options granted under the LTIP and all other outstanding stock options is equal to the market price of PG&E Corporation’s common stock on the date of grant. Stock options generally have a 10-year term and vest over three years of continuous service, subject to accelerated vesting in certain circumstances. As of December 31, 2023, there were no unrecognized compensation costs related to nonvested stock options for PG&E Corporation. The fair value of each stock option on the date of grant is estimated using the Black-Scholes valuation method. No stock options were granted in 2023 or 2022. Expected volatilities are based on historical volatility of PG&E Corporation’s common stock. The expected dividend payment is the dividend yield at the date of grant. The risk-free interest rate for periods within the contractual term of the stock option is based on the U.S. Treasury rates in effect at the date of grant. The expected life of stock options is derived from historical data that estimates stock option exercises and employee departure behavior. There was no tax benefit recognized from stock options for the year ended December 31, 2023. The following table summarizes stock option activity for PG&E Corporation and the Utility for 2023: Number of Weighted Average Grant- Weighted Average Remaining Contractual Term Aggregate Intrinsic Value Outstanding at January 1 2,152,132 $ 7.36 $ — Granted (1) — — — Exercised — — — Forfeited or expired (755,871) 5.80 — Outstanding at December 31 1,396,261 8.20 2.29 — Vested or expected to vest at December 31 1,396,261 8.20 2.29 — Exercisable at December 31 1,396,261 $ 8.20 2.29 $ — (1) Represents additional payout of existing stock option grants. Restricted Stock Units Restricted stock units generally vest equally over three years. Vested restricted stock units are settled in shares of PG&E Corporation common stock accompanied by cash payments to settle any dividend equivalents associated with the vested restricted stock units. Compensation expense is generally recognized ratably over the vesting period based on grant-date fair value. The weighted average grant-date fair value for restricted stock units granted during 2023, 2022, and 2021 was $15.70, $11.40, and $11.01, respectively. The total fair value of restricted stock units that vested during 2023, 2022, and 2021 was $64 million, $46 million, and $19 million, respectively. The tax detriment from restricted stock units that vested in 2023 was $26 million. In general, forfeitures are recorded ratably over the vesting period, using historical averages and adjusted to actuals when vesting occurs. As of December 31, 2023, $74 million of total unrecognized compensation costs related to nonvested restricted stock units was expected to be recognized over the remaining weighted average period of 1.42 years. The following table summarizes restricted stock unit activity for 2023: Number of Weighted Average Grant- Nonvested at January 1 10,978,120 $ 11.21 Granted 4,337,632 15.70 Vested (5,710,073) 11.16 Forfeited (337,254) 12.77 Nonvested at December 31 9,268,425 $ 13.29 Performance Shares Performance shares generally vest three three Compensation expense attributable to performance shares is generally recognized ratably over the applicable three The following table summarizes activity for performance shares in 2023: Number of Weighted Average Grant- Nonvested at January 1 11,022,054 $ 10.68 Granted 4,881,031 13.39 Vested (8,049,294) 9.16 Forfeited (1,251,499) 13.2 Nonvested at December 31 6,602,292 $ 14.06

PREFERRED STOCK

PREFERRED STOCK	12 Months Ended
PREFERRED STOCK	Dec. 31, 2023
Preferred Stock [Abstract]
PREFERRED STOCK	PREFERRED STOCK PG&E Corporation has authorized 400 million shares of preferred stock, none of which is outstanding. The Utility has authorized 75 million shares of first preferred stock, with a par value of $25 per share, and 10 million shares of $100 first preferred stock, with a par value of $100 per share. At December 31, 2023 and 2022, the Utility’s preferred stock outstanding included $145 million of shares with interest rates between 5% and 6% designated as nonredeemable preferred stock and $113 million of shares with interest rates between 4.36% and 5% that are redeemable between $25.75 and $27.25 per share, respectively. The Utility’s preferred stock outstanding are not subject to mandatory redemption. No shares of $100 first preferred stock are outstanding. At December 31, 2023, annual dividends on the Utility’s nonredeemable preferred stock ranged from $1.25 to $1.50 per share. The Utility’s redeemable preferred stock is subject to redemption at the Utility’s option, in whole or in part, if the Utility pays the specified redemption price plus accumulated and unpaid dividends through the redemption date. At December 31, 2023, annual dividends on the Utility’s redeemable preferred stock ranged from $1.09 to $1.25 per share. Dividends on all Utility preferred stock are cumulative. All shares of preferred stock have voting rights and an equal preference in dividend and liquidation rights. Upon liquidation or dissolution of the Utility, holders of preferred stock would be entitled to the par value of such shares plus all accumulated and unpaid dividends, as specified for the class and series. The Utility paid $14 million of dividends on preferred stock in 2023. The Utility paid approximately $70 million of dividends on preferred stock in 2022, of which approximately $59 million was paid in arrears. In addition, on February 14, 2024, the Board of Directors of the Utility declared dividends on its outstanding series of preferred stock, payable on May 15, 2024, to holders of record as of April 30, 2024.

EARNINGS PER SHARE

EARNINGS PER SHARE	12 Months Ended
EARNINGS PER SHARE	Dec. 31, 2023
Earnings Per Share [Abstract]
EARNINGS PER SHARE	EARNINGS PER SHARE PG&E Corporation’s basic EPS is calculated by dividing the income (loss) available for common shareholders by the weighted average number of common shares outstanding. PG&E Corporation applies the treasury stock method of reflecting the dilutive effect of outstanding share-based compensation in the calculation of diluted EPS. The following is a reconciliation of PG&E Corporation’s income (loss) available for common shareholders and weighted average common shares outstanding for calculating diluted EPS for 2023, 2022, and 2021. Year Ended December 31, (in millions, except per share amounts) 2023 2022 2021 Income (loss) available for common shareholders $ 2,242 $ 1,800 $ (102) Weighted average common shares outstanding, basic 2,064 1,987 1,985 Add incremental shares from assumed conversions: Employee share-based compensation 6 8 — Equity Units 68 137 — Weighted average common shares outstanding, diluted 2,138 2,132 1,985 Total earnings (loss) per common share, diluted $ 1.05 $ 0.84 $ (0.05) 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. In addition, as a result of an irrevocable election made on December 8, 2023 to fix the settlement method to combination settlement, the Convertible Notes (as defined in Note 4) did not have a material impact on the calculation of diluted EPS.

INCOME TAXES

INCOME TAXES	12 Months Ended
INCOME TAXES	Dec. 31, 2023
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES PG&E Corporation and the Utility use the asset and liability method of accounting for income taxes. The income tax provision includes current and deferred income taxes resulting from operations during the year. PG&E Corporation and the Utility estimate current period tax expense in addition to calculating DTAs and liabilities. DTAs and liabilities result from temporary tax and accounting timing differences, such as those arising from depreciation expense. PG&E Corporation and the Utility recognize a tax benefit if it is more likely than not that a tax position taken or expected to be taken in a tax return will be sustained upon examination by taxing authorities based on the technical merits of the position. The tax benefit recognized in the financial statements is measured based on the largest amount of benefit that is greater than 50% likely of being realized upon settlement. As such, the difference between a tax position taken or expected to be taken in a tax return in future periods and the benefit recognized and measured pursuant to this guidance in the financial statements represents an unrecognized tax benefit. Investment tax credits are deferred and amortized to income over time. PG&E Corporation amortizes its investment tax credits over the projected investment recovery period. The Utility amortizes its investment tax credits over the life of the related property in accordance with regulatory treatment. PG&E Corporation files a consolidated U.S. federal income tax return that includes the Utility and domestic subsidiaries in which its ownership is 80% or more. PG&E Corporation files a combined state income tax return in California. PG&E Corporation and the Utility are parties to a tax-sharing agreement under which the Utility determines its income tax provision (benefit) on a stand-alone basis. The significant components of income tax provision (benefit) by taxing jurisdiction were as follows: PG&E Corporation Utility Year Ended December 31, (in millions) 2023 2022 2021 2023 2022 2021 Current: Federal $ (1) $ (1) $ — $ (1) $ (1) $ — State — — 1 — — — Deferred: Federal (1,047) (943) 543 (981) (852) 588 State (507) (389) 296 (477) (348) 316 Tax credits (2) (5) (4) (2) (5) (4) Income tax provision (benefit) $ (1,557) $ (1,338) $ 836 $ (1,461) $ (1,206) $ 900 The following tables describe net deferred income tax assets and liabilities: PG&E Corporation Utility Year Ended December 31, (in millions) 2023 2022 2023 2022 Deferred income tax assets: Tax carryforwards $ 9,132 $ 7,156 $ 8,740 $ 6,868 Compensation 145 157 82 80 GHG allowance 361 239 361 239 Wildfire-related claims (1) 1,069 1,489 1,069 1,489 Operating lease liability 142 368 142 368 Transmission tower wireless licenses 250 254 250 254 Bad debt 134 55 134 55 Other (2) 130 142 109 122 Total deferred income tax assets $ 11,363 $ 9,860 $ 10,887 $ 9,475 Deferred income tax liabilities: Property-related basis differences 10,058 9,374 10,047 9,363 Regulatory balancing accounts 1,433 1,376 1,433 1,376 Debt financing costs 428 465 428 465 Operating lease ROU asset 142 368 142 368 Income tax regulatory asset (3) 991 764 991 764 Environmental reserve 200 163 200 163 Other (4) 91 82 82 67 Total deferred income tax liabilities $ 13,343 $ 12,592 $ 13,323 $ 12,566 Total net deferred income tax liabilities $ 1,980 $ 2,732 $ 2,436 $ 3,091 (1) Amounts primarily relate to wildfire-related claims, net of estimated insurance recoveries, and legal and other costs related to various wildfires that have occurred in PG&E Corporation’s and the Utility’s service area over the past several years. (2) Amounts include benefits, state taxes, and customer advances for construction. (3) Represents the tax gross up portion of the deferred income tax for the cumulative differences between amounts recognized for ratemaking purposes and amounts recognized for tax, including the impact of changes in net deferred taxes associated with a lower federal income tax rate as a result of the TCJA. (4) Amounts primarily include property taxes and prepaid expense. The following table reconciles income tax expense at the federal statutory rate to the income tax provision: PG&E Corporation Utility Year Ended December 31, 2023 2022 2021 2023 2022 2021 Federal statutory income tax rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) in income tax rate resulting from: State income tax (net of federal benefit) (1) (57.9) (75.8) 31.3 (34.4) (26.9) 24.1 Effect of regulatory treatment of fixed asset differences (2) (63.4) (123.8) (71.5) (40.1) (49.2) (51.6) Tax credits (2.2) (3.2) (1.7) (2.2) (1.3) (1.2) Fire Victim Trust (3) (126.9) (160.9) 127.3 (80.2) (64.0) 91.9 Other, net (4) 2.2 12.9 5.3 1.1 2.2 2.6 Effective tax rate (227.2) % (329.8) % 111.7 % (134.8) % (118.2) % 86.8 % (1) Includes the effect of state flow-through ratemaking treatment. (2) Includes the effect of federal flow-through ratemaking treatment for certain property-related costs. For these temporary tax differences, PG&E Corporation and the Utility recognize the deferred tax impact in the current period and record offsetting regulatory assets and liabilities. Therefore, PG&E Corporation’s and the Utility’s effective tax rates are impacted as these differences arise and reverse. PG&E Corporation and the Utility recognize such differences as regulatory assets or liabilities as it is probable that these amounts will be recovered from or returned to customers in future rates. In 2023, 2022, and 2021, the amounts also reflect the impact of the amortization of excess deferred tax benefits to be refunded to customers as a result of the TCJA passed in December 2017. (3) Includes an adjustment for the tax benefit of the sale of shares by the Fire Victim Trust in 2023 and 2022 and a DTA write-off associated with the grantor trust election for the Fire Victim Trust in 2021. (4) These amounts primarily represent the impact of tax audit settlements and non-tax deductible penalty costs. Unrecognized Tax Benefits The following table reconciles the changes in unrecognized tax benefits: PG&E Corporation Utility (in millions) 2023 2022 2021 2023 2022 2021 Balance at beginning of year $ 570 $ 498 $ 437 $ 570 $ 498 $ 437 Additions for tax position taken during a prior year 1 — — 1 — — Reductions for tax position taken during a prior year — (1) (23) — (1) (23) Additions for tax position taken during the current year 45 73 85 45 73 85 Settlements — — (1) — — (1) Balance at end of year $ 616 $ 570 $ 498 $ 616 $ 570 $ 498 The component of unrecognized tax benefits that, if recognized, would affect the effective tax rate at December 31, 2023 for PG&E Corporation and the Utility was $33 million. PG&E Corporation’s and the Utility’s unrecognized tax benefits may change significantly within the next 12 months based on tax audit progress. Interest income, interest expense and penalties associated with income taxes are reflected in income tax expense on the Consolidated Statements of Income. For the years ended December 31, 2023, 2022, and 2021, these amounts were immaterial. Tax Audits PG&E Corporation’s tax returns have been accepted through 2015 for federal income tax purposes, except for a few matters, the most significant of which relate to the deductibility of approximately $850 million in repair costs for gas transmission and distribution lines and $400 million in customer bill credits, which the Utility incurred in connection with the decision issued in 2015 for the San Bruno natural gas explosion in September of 2010. The IRS is auditing tax years 2015 through 2018. PG&E Corporation’s tax returns have been accepted through 2014 for California income tax purposes. Tax years 2015 and thereafter remain subject to examination by the State of California. The State of California is auditing tax years 2015 through 2019. Carryforwards The following table describes PG&E Corporation’s operating loss and tax credit carryforward balances: (in millions) December 31, 2023 Expiration Federal: Net operating loss carryforward - Pre-2018 $ 3,447 2031 - 2036 Net operating loss carryforward - Post-2017 29,403 N/A Tax credit carryforward 175 2029 - 2041 State: Net operating loss carryforward $ 32,583 2039 - 2041 Tax credit carryforward 137 Various PG&E Corporation does not believe that the Chapter 11 Cases resulted in loss of or limitation on the utilization of any of the tax carryforwards. PG&E Corporation will continue to monitor the status of tax carryforwards. Other Tax Matters 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’s or the Utility’s ability to use these DTAs to offset taxable income). In general, an ownership change occurs if the aggregate stock ownership of certain shareholders (generally five percent shareholders, applying certain look-through and aggregation rules) increases by more than 50% over such shareholders’ lowest percentage ownership during the testing period (generally three years). The Amended Articles limit Transfers (as defined in the Amended Articles) that increase a person’s or entity’s (including certain groups of persons) ownership of PG&E Corporation’s equity securities to 4.75% or more prior to the Restriction Release Date (as defined in the Amended Articles) without approval by the Board of Directors of PG&E Corporation (the “Ownership Restrictions”). Furthermore, due to the election to treat the Fire Victim Trust as a grantor trust for income tax purposes, the activities of the Fire Victim Trust are treated as activities of the Utility for tax purposes. Accordingly, PG&E Corporation recognized income tax benefits and the corresponding DTA as the Fire Victim Trust sold shares of PG&E Corporation common stock, and the amounts of such benefits and assets were determined largely by the price at which the Fire Victim Trust sold the shares, rather than the price at the time such shares were transferred to the Fire Victim Trust. From inception through December 31, 2023, the Fire Victim Trust exchanged Plan Shares in the aggregate amount of 477,743,590 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. In the year ended December 31, 2023, the Fire Victim Trust’s sale of PG&E Corporation common stock in the aggregate amount of 247,743,590 shares resulted in an aggregate tax benefit of $1.2 billion recorded in PG&E Corporation’s and the Utility’s Consolidated Financial Statements. For more information, see Note 6 above.

DERIVATIVES

DERIVATIVES	12 Months Ended
DERIVATIVES	Dec. 31, 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 Consolidated Balance Sheets and recorded at fair value and on a net basis in accordance with master netting arrangements for each counterparty. The fair value of derivative instruments is further offset by cash collateral paid or received where the right of offset and the intention to offset exist. Price risk management activities that meet the definition of derivatives are recorded at fair value on the Consolidated Balance Sheets. These instruments are not held for speculative purposes and are subject to certain regulatory requirements. The Utility expects to fully recover through rates all costs related to derivatives under the applicable ratemaking mechanism in place as long as the Utility’s price risk management activities are carried out in accordance with CPUC directives. Therefore, all unrealized gains and losses associated with the change in fair value of these derivatives are deferred and recorded within the Utility’s regulatory assets The Utility elects the normal purchase and sale exception for eligible derivatives. Eligible derivatives are those that require physical delivery in quantities that are expected to be used by the Utility over a reasonable period in the normal course of business, and do not contain pricing provisions unrelated to the commodity delivered. These items are not reflected in the Consolidated Balance Sheets at fair value. Volume of Derivative Activity The volumes of the Utility’s outstanding derivatives were as follows: Contract Volume at Underlying Product Instruments December 31, 2023 December 31, 2022 Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 196,063,296 171,212,813 Options 30,695,000 27,785,000 Electricity (MWh) Forwards, Futures and Swaps 9,169,967 10,814,728 Options 92,400 215,600 Congestion Revenue Rights (3) 170,465,674 205,743,505 (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 December 31, 2023, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 134 $ (8) $ 50 $ 176 Other noncurrent assets – other 280 — — 280 Current liabilities – other (172) 8 46 (118) Noncurrent liabilities – other (160) — — (160) Total commodity risk $ 82 $ — $ 96 $ 178 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 Consolidated Statements of Cash Flows. Some of the Utility’s derivative instruments, including power purchase agreements, contain collateral posting provisions tied to the Utility’s credit rating from each of the major credit rating agencies, also known as a credit-risk-related contingent feature. Multiple credit agencies continue to rate the Utility below investment grade, which results in the Utility posting additional collateral. As of December 31, 2023, the Utility satisfied or has otherwise addressed its obligations related to the credit-risk related contingency features.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
FAIR VALUE MEASUREMENTS	Dec. 31, 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 December 31, 2023 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 203 $ — $ — $ — $ 203 Nuclear decommissioning trusts Short-term investments 52 — — — 52 Global equity securities 2,144 — — — 2,144 Fixed-income securities 1,168 909 — — 2,077 Assets measured at NAV — — — — 18 Total nuclear decommissioning trusts (2) 3,364 909 — — 4,291 Customer credit trust Short-term investments 49 — — — 49 Global equity securities 71 — — — 71 Fixed-income securities 29 84 — — 113 Total customer credit trust 149 84 — — 233 Price risk management instruments (Note 10) Electricity — 7 404 (1) 410 Gas — 3 — 43 46 Total price risk management instruments — 10 404 42 456 Rabbi trusts Short-term investments 102 — — — 102 Global equity securities 5 — — — 5 Life insurance contracts — 65 — — 65 Total rabbi trusts 107 65 — — 172 Long-term disability trust Short-term investments 7 — — — 7 Assets measured at NAV — — — — 139 Total long-term disability trust 7 — — — 146 TOTAL ASSETS $ 3,830 $ 1,068 $ 404 $ 42 $ 5,501 Liabilities: Price risk management instruments (Note 10) Electricity $ — $ 43 $ 213 $ (6) $ 250 Gas — 76 — (48) 28 TOTAL LIABILITIES $ — $ 119 $ 213 $ (54) $ 278 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. (2) Represents amount before deducting $717 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 10) 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 10) 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 years ended December 31, 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 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 10 above. Fair Value at (in millions) At December 31, 2023 Valuation Unobservable Fair Value Measurement Assets Liabilities Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 357 $ 134 Market approach CRR auction prices $ (923.72) - 16,696.90 / 1.43 Power purchase agreements $ 47 $ 79 Discounted cash flow Forward prices $ 0.86 - 189.80 / 60.03 (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 years ended December 31, 2023 and 2022, respectively: 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) (8) 233 Asset balance as of December 31 $ 191 $ 199 (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 December 31, 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 December 31, 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 (1) $ 4,548 $ 4,695 $ 4,355 $ 4,490 Utility 35,909 32,866 32,847 27,666 (1) As of December 31, 2023, the net carrying amount and the estimated fair value (Level 2) of the Convertible Notes were $2.1 billion and $2.2 billion, respectively. Nuclear Decommissioning Trust Investments The following table provides a summary of equity securities and available-for-sale debt securities: (in millions) Amortized Total Total Total Fair As of December 31, 2023 Nuclear decommissioning trusts Short-term investments $ 52 $ — $ — $ 52 Global equity securities 381 1,792 (11) 2,162 Fixed-income securities 2,103 60 (86) 2,077 Total (1) $ 2,536 $ 1,852 $ (97) $ 4,291 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 $717 million and $575 million as of December 31, 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) December 31, 2023 Less than 1 year $ 9 1–5 years 665 5–10 years 463 More than 10 years 940 Total maturities of fixed-income securities $ 2,077 The following table provides a summary of activity for the fixed-income and equity securities: (in millions) 2023 2022 2021 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 2,235 $ 3,316 $ 1,678 Gross realized gains on securities 80 2 286 Gross realized losses on securities (74) (3) (19) 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 December 31, 2023 Customer credit trust Short-term investments $ 49 $ — $ — $ 49 Global equity securities 56 16 (1) 71 Fixed-income securities 111 2 — 113 Total $ 216 $ 18 $ (1) $ 233 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) December 31, 2023 Less than 1 year $ — 1–5 years 25 5–10 years 29 More than 10 years 59 Total maturities of fixed-income securities $ 113 The following table provides a summary of activity for the fixed-income and equity securities: (in millions) 2023 2022 Proceeds from sales and maturities of customer credit trust investments $ 556 $ 250 Gross realized gains on securities 23 10 Gross realized losses on securities (1) (19) (41) (1) Includes $4 million and $6 million of impaired debt securities which were written down to their respective fair values during the year ended December 31, 2023 and the year ended December 31, 2022, respectively.

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	12 Months Ended
EMPLOYEE BENEFIT PLANS	Dec. 31, 2023
Employee Benefit and Share-Based Payment Arrangement, Noncash Expense [Abstract]
EMPLOYEE BENEFIT PLANS	EMPLOYEE BENEFIT PLANS Pension Plan and Postretirement Benefits Other than Pensions (“PBOP”) PG&E Corporation and the Utility sponsor a non-contributory defined benefit pension plan for eligible employees hired before December 31, 2012 and a cash balance plan for those eligible employees hired after this date or who made a one-time election to participate (“Pension Plan”). Certain trusts underlying these plans are qualified trusts under the IRC. If certain conditions are met, PG&E Corporation and the Utility can deduct payments made to the qualified trusts, subject to certain limitations. PG&E Corporation’s and the Utility’s funding policy is to contribute tax-deductible amounts, consistent with applicable regulatory decisions and federal minimum funding requirements. On an annual basis, the Utility funds the pension plan up to the amount it is authorized to recover through rates. PG&E Corporation and the Utility also sponsor contributory postretirement medical plans for retirees and their eligible dependents, and non-contributory postretirement life insurance plans for eligible employees and retirees. PG&E Corporation and the Utility use a fiscal year-end measurement date for all plans. Change in Plan Assets, Benefit Obligations, and Funded Status The following tables show the reconciliation of changes in plan assets, benefit obligations, and the plans’ aggregate funded status for pension benefits and other benefits for PG&E Corporation during 2023 and 2022: Pension Plan (in millions) 2023 2022 Change in plan assets: Fair value of plan assets at beginning of year $ 16,369 $ 21,895 Actual return on plan assets 1,518 (4,916) Company contributions 336 339 Benefits and expenses paid (1,012) (949) Fair value of plan assets at end of year $ 17,211 $ 16,369 Change in benefit obligation: Benefit obligation at beginning of year $ 16,608 $ 22,759 Service cost for benefits earned 379 575 Interest cost 913 692 Actuarial loss (gain) (1) 809 (6,471) Plan amendments — — Benefits and expenses paid (1,012) (947) Benefit obligation at end of year (2) $ 17,697 $ 16,608 Funded Status: Current liability $ (9) $ (8) Noncurrent liability (477) (231) Net liability at end of year $ (486) $ (239) (1) The actuarial loss for the year ended December 31, 2023 was due to a decrease in the discount rate used to measure the projected benefit obligation and unfavorable changes in the demographic assumptions; the actuarial gain for the year ended December 31, 2022 was due to an increase in the discount rate used to measure the projected benefit obligation, offset by unfavorable changes in the demographic assumptions. (2) PG&E Corporation’s accumulated benefit obligation was $16.3 billion and $15.4 billion at December 31, 2023 and 2022, respectively. Postretirement Benefits Other than Pensions (in millions) 2023 2022 Change in plan assets: Fair value of plan assets at beginning of year $ 2,336 $ 3,102 Actual return on plan assets 260 (693) Company contributions 5 26 Plan participant contribution 81 81 Benefits and expenses paid (183) (180) Fair value of plan assets at end of year $ 2,499 $ 2,336 Change in benefit obligation: Benefit obligation at beginning of year $ 1,339 $ 1,766 Service cost for benefits earned 38 62 Interest cost 73 53 Actuarial loss (gain) (1) 8 (486) Benefits and expenses paid (165) (162) Federal subsidy on benefits paid 3 3 Plan participant contributions 81 81 Voluntary separation program-related termination benefits (2) — 22 Benefit obligation at end of year $ 1,377 $ 1,339 Funded Status: (3) Noncurrent asset $ 1,122 $ 997 Noncurrent liability — — Net asset at end of year $ 1,122 $ 997 (1) The actuarial loss for the year ended December 31, 2023 was primarily due to a decrease in the discount rate used to measure the accumulated benefit obligations, offset by favorable changes in claims cost and demographic assumptions. The actuarial gain for the year ended December 31, 2022 was primarily due to an increase in the discount rate used to measure the accumulated benefit obligations, offset by unfavorable changes in demographic assumptions. (2) Represents voluntary separation program related credits to employee retirement health savings accounts. See “Voluntary Separation Program” in Note 3 of the Notes to the Consolidated Financial Statements in Item 8 of the 2022 Form 10-K. (3) At December 31, 2023 and 2022, the postretirement medical plan and the postretirement life insurance plan were in overfunded positions. The projected benefit obligation and the fair value of plan assets for the postretirement life insurance plan were $275 million and $292 million as of December 31, 2023, and $259 million and $266 million as of December 31, 2022, respectively. There was no material difference between PG&E Corporation and the Utility for the information disclosed above. Components of Net Periodic Benefit Cost PG&E Corporation and the Utility sponsor a non-contributory defined benefit pension plan and cash balance plan. Both plans are included in “Pension Benefits” below. Post-retirement medical and life insurance plans are included in “Other Benefits” below. Net periodic benefit costs as reflected in PG&E Corporation’s Consolidated Statements of Income were as follows: Pension Plan (in millions) 2023 2022 2021 Service cost for benefits earned (1) $ 379 $ 575 $ 587 Interest cost 913 692 645 Expected return on plan assets (981) (1,189) (1,046) Amortization of prior service cost (4) (4) (6) Amortization of net actuarial loss 1 2 6 Net periodic benefit cost 308 76 186 Less: transfer to regulatory account (2) 25 254 147 Total expense recognized $ 333 $ 330 $ 333 (1) A portion of service costs are capitalized pursuant to ASU 2017-07. (2) The Utility recorded these amounts to a regulatory account as they are probable of recovery through future rates. Postretirement Benefits Other than Pensions (in millions) 2023 2022 2021 Service cost for benefits earned (1) $ 38 $ 62 $ 63 Interest cost 73 53 51 Expected return on plan assets (132) (130) (137) Amortization of prior service cost 3 7 14 Amortization of net actuarial gain (19) (40) (33) Special termination benefits — 22 — Net periodic benefit cost $ (37) $ (26) $ (42) (1) A portion of service costs are capitalized pursuant to ASU 2017-07. Non-service costs are reflected in Other income, net on the Consolidated Statements of Income. Service costs are reflected in Operating and maintenance on the Consolidated Statements of Income. There was no material difference between PG&E Corporation and the Utility for the information disclosed above. Components of Accumulated Other Comprehensive Income PG&E Corporation and the Utility record unrecognized prior service costs and unrecognized gains and losses related to pension and post-retirement benefits other than pension as components of accumulated other comprehensive income, net of tax. In addition, regulatory adjustments are recorded in the Consolidated Statements of Income and Consolidated Balance Sheets to reflect the difference between expense or income calculated in accordance with GAAP for accounting purposes and expense or income for ratemaking purposes, which is based on authorized plan contributions. For pension benefits, a regulatory asset or liability is recorded for amounts that would otherwise be recorded to accumulated other comprehensive income. For post-retirement benefits other than pension, the Utility generally records a regulatory liability for amounts that would otherwise be recorded to accumulated other comprehensive income. As the Utility is unable to record a regulatory asset for these other benefits, the charge remains in accumulated other comprehensive income (loss). Valuation Assumptions The following weighted average year-end actuarial assumptions were used in determining the plans’ projected benefit obligations and net benefit costs. Pension Plan PBOP Plans December 31, December 31, 2023 2022 2021 2023 2022 2021 Discount rate 5.21 % 5.54 % 3.03 % 5.18 - 5.22% 5.50 - 5.54% 2.97 - 3.04% Rate of future compensation increases 3.80 % 3.80 % 3.80 % N/A N/A N/A Expected return on plan assets 6.00 % 6.10 % 5.50 % 3.70 - 7.00% 3.70 - 7.30% 3.30 - 6.40% Interest crediting rate for cash balance plan 3.86 % 4.19 % 1.95 % N/A N/A N/A The assumed health care cost trend rate as of December 31, 2023 was 6.25%, gradually decreasing to the ultimate trend rate of approximately 4.5% in 2031 and beyond. Expected rates of return on plan assets were developed by estimating future stock and bond returns and then applying these returns to the target asset allocations of the employee benefit plan trusts, resulting in a weighted average rate of return on plan assets. Returns on fixed-income debt investments were projected based on real maturity and credit spreads added to a long-term inflation rate. Returns on equity investments were projected based on estimates of dividend yield and real earnings growth added to a long-term inflation rate. For the pension plan, the assumed return of 6.0% compares to a ten-year actual return of 5.3%. The rate used to discount pension benefits and other benefits was based on a yield curve developed from market data of over approximately 858 Aa-grade non-callable bonds at December 31, 2023. This yield curve has discount rates that vary based on the duration of the obligations. The estimated future cash flows for the pension benefits and other benefit obligations were matched to the corresponding rates on the yield curve to derive a weighted average discount rate. Investment Policies and Strategies The financial position of PG&E Corporation’s and the Utility’s funded status is the difference between the fair value of plan assets and projected benefit obligations. Volatility in funded status occurs when asset values change differently from liability values and can result in fluctuations in costs in financial reporting, as well as the amount of minimum contributions required under the Employee Retirement Income Security Act of 1974, as amended. PG&E Corporation’s and the Utility’s investment policies and strategies are designed to increase the ratio of trust assets to plan liabilities at an acceptable level of funded status volatility. The trusts’ asset allocations are meant to manage volatility, reduce costs, and diversify its holdings. Interest rate, credit, and equity risk are the key determinants of PG&E Corporation’s and the Utility’s funded status volatility. In addition to affecting the trusts’ fixed income portfolio market values, interest rate changes also influence liability valuations as discount rates move with current bond yields. To manage volatility, PG&E Corporation’s and the Utility’s trusts hold significant allocations in long maturity fixed-income investments. Although they contribute to funded status volatility, equity investments are held to reduce long-term funding costs due to their higher expected return. Real assets and absolute return investments are held to diversify the trust’s holdings in equity and fixed-income investments by exhibiting returns with low correlation to the direction of these markets. Real assets include global real estate investment trusts (“REITS”), global listed infrastructure equities, and private real estate funds. Absolute return investments include hedge fund portfolios. Derivative instruments such as equity index futures are used to meet target equity exposure. Derivative instruments, such as equity index futures and U.S. treasury futures, are also used to rebalance the allocation between fixed income and equity of the pension’s portfolio. Foreign currency exchange contracts are used to hedge a portion of the non-U.S. dollar exposure of global equity investments. The target asset allocation percentages for major categories of trust assets for pension and other benefit plans are as follows: Pension Plan PBOP Plans 2024 2023 2022 2024 2023 2022 Global equity securities 26 % 26 % 30 % 29 % 28 % 26 % Absolute return 1 % 1 % 2 % — % 1 % 1 % Real assets 8 % 8 % 8 % 3 % 3 % 3 % Fixed-income securities 65 % 65 % 60 % 68 % 68 % 70 % Total 100 % 100 % 100 % 100 % 100 % 100 % PG&E Corporation and the Utility apply a risk management framework for managing the risks associated with employee benefit plan trust assets. The guiding principles of this risk management framework are the clear articulation of roles and responsibilities, appropriate delegation of authority, and proper accountability and documentation. Trust investment policies and investment manager guidelines include provisions designed to ensure prudent diversification, manage risk through appropriate use of physical direct asset holdings and derivative securities, and identify permitted and prohibited investments. Fair Value Measurements The following tables present the fair value of plan assets for pension and other benefits plans by major asset category at December 31, 2023 and 2022. Fair Value Measurements At December 31, 2023 2022 (in millions) Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Pension Plan: Short-term investments $ 565 $ 86 $ — $ 651 $ 461 $ 126 $ — $ 587 Global equity securities 1,270 — — 1,270 1,430 — — 1,430 Real assets 472 — — 472 426 — — 426 Fixed-income securities 1,926 6,802 13 8,741 1,946 6,086 8 8,040 Assets measured at NAV — — — 6,080 — — — 5,886 Total $ 4,233 $ 6,888 $ 13 $ 17,214 $ 4,263 $ 6,212 $ 8 $ 16,369 PBOP Plans: Short-term investments $ 30 $ — $ — $ 30 $ 26 $ — $ — $ 26 Global equity securities 66 — — 66 83 — — 83 Real assets 32 — — 32 29 — — 29 Fixed-income securities 422 795 1 1,218 406 702 1 1,109 Assets measured at NAV — — — 1,160 — — — 1,100 Total $ 550 $ 795 $ 1 $ 2,506 $ 544 $ 702 $ 1 $ 2,347 Total plan assets at fair value $ 19,720 $ 18,716 In addition to the total plan assets disclosed at fair value in the table above, the trusts had other net liabilities of $10 million and $11 million at December 31, 2023 and 2022, respectively, comprised primarily of cash, accounts receivable, deferred taxes, and accounts payable. Valuation Techniques The following describes the valuation techniques used to measure the fair value of the assets and liabilities shown in the table above. All investments that are valued using a NAV per share can be redeemed quarterly with a notice not to exceed 90 days. Short-Term Investments Short-term investments consist primarily of commingled funds across government, credit, and asset-backed sectors. These securities are categorized as Level 1 and Level 2 assets. Global Equity Securities The global equity category includes investments in common stock and equity-index futures. Equity investments in common stock are actively traded on public exchanges and are therefore considered Level 1 assets. These equity investments are generally valued based on unadjusted prices in active markets for identical securities. Equity-index futures are valued based on unadjusted prices in active markets and are Level 1 assets. Real Assets The real asset category includes portfolios of commodity futures, global REITS, global listed infrastructure equities, and private real estate funds. The commodity futures, global REITS, and global listed infrastructure equities are actively traded on a public exchange and are therefore considered Level 1 assets. Fixed-Income Securities Fixed-income securities are primarily composed of U.S. government and agency securities, municipal securities, and other fixed-income securities, including corporate debt securities. U.S. government and agency securities primarily consist of U.S. Treasury securities that are classified as Level 1 because the fair value is determined by observable market prices in active markets. A market approach is generally used to estimate the fair value of debt securities classified as Level 2 using evaluated pricing data such as broker quotes, for similar securities adjusted for observable differences. Significant inputs used in the valuation model generally include benchmark yield curves and issuer spreads. The external credit ratings, coupon rate, and maturity of each security are considered in the valuation model, as applicable. Assets Measured at NAV Using Practical Expedient Investments in the trusts that are measured at fair value using the NAV per share practical expedient have not been classified in the fair value hierarchy tables above. The fair value amounts are included in the tables above in order to reconcile to the amounts presented in the Consolidated Balance Sheets. These investments include commingled funds that are composed of equity securities traded publicly on exchanges, fixed-income securities that are composed primarily of U.S. government securities, credit securities and asset-backed securities, and real assets and absolute return investments that are held to diversify the trust’s holdings in equity and fixed-income securities. Transfers Between Levels No material transfers between levels occurred in the years ended December 31, 2023 or 2022. Level 3 Reconciliation The following table is a reconciliation of changes in the fair value of instruments for the pension plan that have been classified as Level 3 for the years ended December 31, 2023 and 2022: (in millions) For the year ended December 31, 2023 Fixed-Income Balance at beginning of year $ 8 Actual return on plan assets: Relating to assets still held at the reporting date 2 Relating to assets sold during the period (1) Purchases, issuances, sales, and settlements: Purchases 10 Settlements (6) Balance at end of year $ 13 (in millions) For the year ended December 31, 2022 Fixed-Income Balance at beginning of year $ 27 Actual return on plan assets: Relating to assets still held at the reporting date 1 Relating to assets sold during the period — Purchases, issuances, sales, and settlements: Purchases 6 Settlements (26) Balance at end of year $ 8 There were no material transfers out of Level 3 in 2023 or 2022. Cash Flow Information Employer Contributions PG&E Corporation and the Utility contributed $336 million to the pension benefit plans, $31 million to the long-term disability trusts, and $5 million to the other postretirement benefit plans in 2023. These contributions are consistent with PG&E Corporation’s and the Utility’s funding policy, which is to contribute amounts that are tax-deductible and consistent with applicable regulatory decisions and federal minimum funding requirements. The Utility’s pension benefits met all the funding requirements under the Employee Retirement Income Security Act. PG&E Corporation and the Utility expect to make total contributions of approximately $327 million to the pension plan in 2024. PG&E Corporation and the Utility plan to contribute $31 million to the long-term disability trusts in 2024, as authorized in the 2023 GRC. Benefits Payments and Receipts As of December 31, 2023, the estimated benefits expected to be paid and the estimated federal subsidies expected to be received in each of the next five fiscal years, and in aggregate for the five fiscal years thereafter, are as follows: (in millions) Pension PBOP Federal 2024 957 93 (4) 2025 1,040 93 (1) 2026 1,066 96 (1) 2027 1,089 87 (1) 2028 1,111 89 (1) Thereafter in the succeeding five years 5,802 471 (4) There were no material differences between the estimated benefits expected to be paid by PG&E Corporation and paid by the Utility for the years presented above. There were also no material differences between the estimated subsidies expected to be received by PG&E Corporation and received by the Utility for the years presented above. Retirement Savings Plan PG&E Corporation sponsors a retirement savings plan, which qualifies as a 401(k) defined contribution benefit plan under the IRC. This plan permits eligible employees to make pre-tax and after-tax contributions into the plan and provides for employer contributions to be made to eligible participants. Total expenses recognized for defined contribution benefit plans reflected in PG&E Corporation’s Consolidated Statements of Income were $158 million, $144 million, and $133 million in 2023, 2022, and 2021, respectively. Beginning January 1, 2019 PG&E Corporation changed its default matching contributions under its 401(k) plan from PG&E Corporation common stock to cash. Beginning in March 2019, at PG&E Corporation’s directive, the 401(k) plan trustee began purchasing new shares in the PG&E Corporation common stock fund on the open market rather than directly from PG&E Corporation. There were no material differences between the employer contribution expense for PG&E Corporation and the Utility for the years presented above.

RELATED PARTY AGREEMENTS AND TR

RELATED PARTY AGREEMENTS AND TRANSACTIONS	12 Months Ended
RELATED PARTY AGREEMENTS AND TRANSACTIONS	Dec. 31, 2023
Related Party Transactions [Abstract]
RELATED PARTY AGREEMENTS AND TRANSACTIONS	RELATED PARTY AGREEMENTS AND TRANSACTIONS The Utility and other subsidiaries provide and receive various services to and from their parent, PG&E Corporation, and among themselves. The Utility and PG&E Corporation exchange administrative and professional services in support of operations. Services provided directly to PG&E Corporation by the Utility are priced at the higher of fully loaded cost (i.e., direct cost of good or service and allocation of overhead costs) or fair market value, depending on the nature of the services. Services provided directly to the Utility by PG&E Corporation are generally priced at the lower of fully loaded cost or fair market value, depending on the nature and value of the services. PG&E Corporation also allocates various corporate administrative and general costs to the Utility and other subsidiaries using agreed-upon allocation factors, including the number of employees, operating and maintenance expenses, total assets, and other cost allocation methodologies. Management believes that the methods used to allocate expenses are reasonable and meet the reporting and accounting requirements of its regulatory agencies. The Utility’s significant related party transactions were: Year Ended December 31, (in millions) 2023 2022 2021 Utility revenues from: Administrative services provided to PG&E Corporation $ 3 $ 3 $ 3 Utility expenses from: Administrative services received from PG&E Corporation $ 80 $ 104 $ 82 Utility employee benefit due to PG&E Corporation 74 85 39 At December 31, 2023 and 2022, the Utility had receivables of $26 million and $33 million, respectively, from PG&E Corporation included in Accounts receivable – other and Noncurrent assets – other on the Utility’s Consolidated Balance Sheets, and payables of $24 million and $46 million, respectively, to PG&E Corporation included in accounts payable – other on the Utility’s Consolidated Balance Sheets.

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES	12 Months Ended
WILDFIRE-RELATED CONTINGENCIES	Dec. 31, 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. PG&E Corporation and the Utility record a provision for a loss contingency when they determine that 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. Unless expressly noted otherwise, the loss accruals in this Note reflect the lower end of the range of the reasonably estimable range of losses. PG&E Corporation and the Utility believe that it is reasonably possible that the amount of loss could be greater than the accrued estimated amounts but are unable to reasonably estimate the additional loss or the upper end of the range because, as described below, there are a number of unknown facts and legal considerations that may impact the amount of any potential liability, including the total scope and nature of claims that may be asserted against PG&E Corporation and the Utility. 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 power 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. If the liability for wildfires were to exceed $1.0 billion in the aggregate in any Coverage Year, the Utility may be eligible to make a claim to the Wildfire Fund under AB 1054 to satisfy settled or finally adjudicated eligible claims in excess of such amount, except that claims related to the 2019 Kincade fire would be subject to the 40% limitation on the allowed amount of claims arising before emergence from bankruptcy. PG&E Corporation and the Utility intend to continue to review the available information and other information as it becomes available, including evidence in the possession of Cal Fire, USFS, or the relevant district attorney’s office, evidence from or held by other parties, claims that have not yet been submitted, and additional information about the nature and extent of personal and business property damages and losses, the nature, number and severity of personal injuries, and information made available through the discovery process. The following table presents the cumulative charges PG&E Corporation and the Utility have paid through December 31, 2023. Payments (in millions) 2019 Kincade Fire $ 667 2020 Zogg Fire 390 2021 Dixie Fire 731 2022 Mosquito Fire 15 Total at December 31, 2023 $ 1,803 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 February 14, 2024, PG&E Corporation and the Utility are aware of approximately 132 complaints on behalf of at least 2,913 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. On July 28, 2023, the court scheduled a new trial date for August 26, 2024. PG&E Corporation and the Utility are also aware of a complaint on behalf of Geysers Power Company, Calpine Corporation, and CPN Insurance Corporation. 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 August 8, 2023, PG&E Corporation and the Utility entered into an agreement with Cal Fire to resolve its claims arising from the 2019 Kincade fire. On January 24, 2024, Cal Fire filed a request to dismiss its complaint with prejudice in the coordinated proceeding, which the court entered. 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. 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). Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this filing, including their experience with settlements, PG&E Corporation and the Utility recorded an additional charge in the fourth quarter of 2023 for probable losses in connection with the 2019 Kincade fire of $100 million for an aggregate liability of $1.125 billion (before available insurance). PG&E Corporation’s and the Utility’s accrued estimated losses of $1.125 billion do not include, among other things: (i) any punitive damages, (ii) any amounts in respect of compensation claims by federal or state agencies other than state fire suppression costs, or (iii) 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 100 Payments (292) Balance at December 31, 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, which was fully collected as of December 31, 2023. 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. As of February 14, 2024, PG&E Corporation and the Utility have settled or reached settlements in principle with substantially all individual plaintiffs. 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 December 31, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses represent the best estimate of the liability and does not include any claims related to the Cal OES complaint or any punitive damages. The following table presents changes in the best estimate 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 (22) Balance at December 31, 2023 $ 10 The Utility has liability insurance for third-party liability attributable to the 2020 Zogg fire in an aggregate amount of $611 million. As of December 31, 2023, the Utility recorded an insurance receivable for $374 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 $34 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, through its ongoing investigation, 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” below.) 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. On October 9, 2023, the SED submitted for adoption by the CPUC a draft resolution approving an Administrative Consent Order and Agreement between the SED and the Utility (the “Dixie ACO”). The Dixie ACO would resolve the SED’s investigation into the 2021 Dixie fire. The Dixie ACO provides that the Utility would (i) pay $2.5 million to California’s General Fund; (ii) pay $2.5 million to tribes impacted by the 2021 Dixie fire; (iii) and undertake an initiative to transition to electronic records for specified patrols and inspections of distribution facilities, at an approximate cost of $40 million over five years, and the Utility may not seek recovery of such costs. The SED agreed to refrain from instituting any further enforcement proceedings against the Utility related to the 2021 Dixie fire. The Dixie ACO 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. The Dixie ACO also states that the parties to it intend that it shall not affect whether the Utility may obtain recovery of costs and expenses incurred in connection with the 2021 Dixie fire, including for amounts drawn from the Wildfire Fund or otherwise sought through a cost recovery application to the CPUC. On February 2, 2024, the CPUC issued a final decision approving the Dixie ACO. In connection with the Dixie ACO, PG&E Corporation and the Utility recorded a liability of $5 million reflected in Other current liabilities on the Consolidated Financial Statements as of December 31, 2023. For the recordkeeping initiative costs for which the Utility will not seek recovery, the Utility expects to record disallowances as such costs are incurred. As of February 14, 2024, PG&E Corporation and the Utility are aware of approximately 161 complaints on behalf of at least 8,387 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. On September 20, 2023, the court vacated the November 8, 2023 trial date and scheduled a new trial date for April 2, 2024. On June 30, 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 January 17, 2023, PG&E Corporation and the Utility reached an agreement with certain public entities to settle their claims for $24 million. 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. 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). Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this filing, including their experience to date in settling the claims of individual plaintiffs, PG&E Corporation and the Utility recorded an additional charge in the third quarter of 2023 for probable losses in connection with the 2021 Dixie fire of $425 million for an aggregate liability of $1.6 billion (before available insurance) as of December 31, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses of $1.6 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) medical monitoring costs, or (v) any other amounts that are not reasonably estimable. As noted above, the aggregate estimated liability for claims in connection with the 2021 Dixie fire does not include potential claims for fire suppression costs from federal, state, county, or local agencies or damage to land and vegetation in national parks or national forests. As to these damages, PG&E Corporation and the Utility have not concluded that a loss is probable. 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 parks 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 425 Payments (686) Balance at December 31, 2023 $ 870 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 December 31, 2023, the Utility recorded an insurance receivable of $526 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 $374 million insurance receivable recorded in connection with the 2020 Zogg fire. As of December 31, 2023, the Utility recorded a Wildfire Fund receivable of $600 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. As of December 31, 2023, the Utility also recorded a $91 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 $470 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. 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 United States Department of Justice (“DOJ”), and PG&E Corporation and the Utility are cooperating with the investigation. 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 is investigating the 2022 Mosquito fire, and other entities may also be investigating. It is uncertain when any such investigations will be complete. As of February 14, 2024, PG&E Corporation and the Utility are aware of approximately six complaints on behalf of at least 233 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. The plaintiffs seek damages that include property damage, economic loss, punitive damages, exemplary damages, attorneys’ fees and other damages. On November 13, 2023, PG&E Corporation and the Utility entered into an agreement with the insurance subrogation plaintiffs in the 2022 Mosquito fire litigation to resolve their claims arising from the 2022 Mosquito 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 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 December 31, 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, or (iv) any other amounts that are not reasonably estimable. 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 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 2022 Mosquito fire. 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 2022 Mosquito fire since December 31, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 99 Accrued Losses — Payments (14) Balance at December 31, 2023 $ 85 The Utility has liability insurance coverage for third-party liability in an aggregate amount of $733 million, with a deductible of $60 million. As of December 31, 2023, the Utility recorded an insurance receivable of $63 million for probable insurance recoveries in connection with the 2022 Mosquito fire, including legal fees. As of December 31, 2023, the Utility also recorded a $8 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 $52 million regulatory asset for costs that were determined to be probable of recovery through the WEMA. See “Regulatory Recovery” below. Loss Recoveries PG&E Corporation and the Utility have recovery mechanisms available for wildfire liabilities including from insurance, customers, and the Wildfire Fund. PG&E Corporation and the Utility recor

OTHER CONTINGENCIES AND COMMITM

OTHER CONTINGENCIES AND COMMITMENTS	12 Months Ended
OTHER CONTINGENCIES AND COMMITMENTS	Dec. 31, 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. PG&E Corporation and the Utility record a provision for a loss contingency when they determine that 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. Unless expressly noted otherwise, the loss accruals in this Note reflect the lower end of the range of the reasonably estimable range of losses. PG&E Corporation and the Utility believe that it is reasonably possible that the amount of loss could be greater than the accrued estimated amounts but are unable to reasonably estimate the additional loss or the upper end of the range because, as described below, there are a number of unknown facts and legal considerations that may impact the amount of any potential liability, including the total scope and nature of claims that may be asserted against PG&E Corporation and the Utility. 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 power 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. If the liability for wildfires were to exceed $1.0 billion in the aggregate in any Coverage Year, the Utility may be eligible to make a claim to the Wildfire Fund under AB 1054 to satisfy settled or finally adjudicated eligible claims in excess of such amount, except that claims related to the 2019 Kincade fire would be subject to the 40% limitation on the allowed amount of claims arising before emergence from bankruptcy. PG&E Corporation and the Utility intend to continue to review the available information and other information as it becomes available, including evidence in the possession of Cal Fire, USFS, or the relevant district attorney’s office, evidence from or held by other parties, claims that have not yet been submitted, and additional information about the nature and extent of personal and business property damages and losses, the nature, number and severity of personal injuries, and information made available through the discovery process. The following table presents the cumulative charges PG&E Corporation and the Utility have paid through December 31, 2023. Payments (in millions) 2019 Kincade Fire $ 667 2020 Zogg Fire 390 2021 Dixie Fire 731 2022 Mosquito Fire 15 Total at December 31, 2023 $ 1,803 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 February 14, 2024, PG&E Corporation and the Utility are aware of approximately 132 complaints on behalf of at least 2,913 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. On July 28, 2023, the court scheduled a new trial date for August 26, 2024. PG&E Corporation and the Utility are also aware of a complaint on behalf of Geysers Power Company, Calpine Corporation, and CPN Insurance Corporation. 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 August 8, 2023, PG&E Corporation and the Utility entered into an agreement with Cal Fire to resolve its claims arising from the 2019 Kincade fire. On January 24, 2024, Cal Fire filed a request to dismiss its complaint with prejudice in the coordinated proceeding, which the court entered. 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. 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). Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this filing, including their experience with settlements, PG&E Corporation and the Utility recorded an additional charge in the fourth quarter of 2023 for probable losses in connection with the 2019 Kincade fire of $100 million for an aggregate liability of $1.125 billion (before available insurance). PG&E Corporation’s and the Utility’s accrued estimated losses of $1.125 billion do not include, among other things: (i) any punitive damages, (ii) any amounts in respect of compensation claims by federal or state agencies other than state fire suppression costs, or (iii) 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 100 Payments (292) Balance at December 31, 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, which was fully collected as of December 31, 2023. 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. As of February 14, 2024, PG&E Corporation and the Utility have settled or reached settlements in principle with substantially all individual plaintiffs. 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 December 31, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses represent the best estimate of the liability and does not include any claims related to the Cal OES complaint or any punitive damages. The following table presents changes in the best estimate 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 (22) Balance at December 31, 2023 $ 10 The Utility has liability insurance for third-party liability attributable to the 2020 Zogg fire in an aggregate amount of $611 million. As of December 31, 2023, the Utility recorded an insurance receivable for $374 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 $34 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, through its ongoing investigation, 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” below.) 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. On October 9, 2023, the SED submitted for adoption by the CPUC a draft resolution approving an Administrative Consent Order and Agreement between the SED and the Utility (the “Dixie ACO”). The Dixie ACO would resolve the SED’s investigation into the 2021 Dixie fire. The Dixie ACO provides that the Utility would (i) pay $2.5 million to California’s General Fund; (ii) pay $2.5 million to tribes impacted by the 2021 Dixie fire; (iii) and undertake an initiative to transition to electronic records for specified patrols and inspections of distribution facilities, at an approximate cost of $40 million over five years, and the Utility may not seek recovery of such costs. The SED agreed to refrain from instituting any further enforcement proceedings against the Utility related to the 2021 Dixie fire. The Dixie ACO 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. The Dixie ACO also states that the parties to it intend that it shall not affect whether the Utility may obtain recovery of costs and expenses incurred in connection with the 2021 Dixie fire, including for amounts drawn from the Wildfire Fund or otherwise sought through a cost recovery application to the CPUC. On February 2, 2024, the CPUC issued a final decision approving the Dixie ACO. In connection with the Dixie ACO, PG&E Corporation and the Utility recorded a liability of $5 million reflected in Other current liabilities on the Consolidated Financial Statements as of December 31, 2023. For the recordkeeping initiative costs for which the Utility will not seek recovery, the Utility expects to record disallowances as such costs are incurred. As of February 14, 2024, PG&E Corporation and the Utility are aware of approximately 161 complaints on behalf of at least 8,387 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. On September 20, 2023, the court vacated the November 8, 2023 trial date and scheduled a new trial date for April 2, 2024. On June 30, 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 January 17, 2023, PG&E Corporation and the Utility reached an agreement with certain public entities to settle their claims for $24 million. 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. 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). Based on the facts and circumstances available to PG&E Corporation and the Utility as of the date of this filing, including their experience to date in settling the claims of individual plaintiffs, PG&E Corporation and the Utility recorded an additional charge in the third quarter of 2023 for probable losses in connection with the 2021 Dixie fire of $425 million for an aggregate liability of $1.6 billion (before available insurance) as of December 31, 2023. PG&E Corporation’s and the Utility’s accrued estimated losses of $1.6 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) medical monitoring costs, or (v) any other amounts that are not reasonably estimable. As noted above, the aggregate estimated liability for claims in connection with the 2021 Dixie fire does not include potential claims for fire suppression costs from federal, state, county, or local agencies or damage to land and vegetation in national parks or national forests. As to these damages, PG&E Corporation and the Utility have not concluded that a loss is probable. 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 parks 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 425 Payments (686) Balance at December 31, 2023 $ 870 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 December 31, 2023, the Utility recorded an insurance receivable of $526 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 $374 million insurance receivable recorded in connection with the 2020 Zogg fire. As of December 31, 2023, the Utility recorded a Wildfire Fund receivable of $600 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. As of December 31, 2023, the Utility also recorded a $91 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 $470 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. 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 United States Department of Justice (“DOJ”), and PG&E Corporation and the Utility are cooperating with the investigation. 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 is investigating the 2022 Mosquito fire, and other entities may also be investigating. It is uncertain when any such investigations will be complete. As of February 14, 2024, PG&E Corporation and the Utility are aware of approximately six complaints on behalf of at least 233 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. The plaintiffs seek damages that include property damage, economic loss, punitive damages, exemplary damages, attorneys’ fees and other damages. On November 13, 2023, PG&E Corporation and the Utility entered into an agreement with the insurance subrogation plaintiffs in the 2022 Mosquito fire litigation to resolve their claims arising from the 2022 Mosquito 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 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 December 31, 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, or (iv) any other amounts that are not reasonably estimable. 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 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 2022 Mosquito fire. 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 2022 Mosquito fire since December 31, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 99 Accrued Losses — Payments (14) Balance at December 31, 2023 $ 85 The Utility has liability insurance coverage for third-party liability in an aggregate amount of $733 million, with a deductible of $60 million. As of December 31, 2023, the Utility recorded an insurance receivable of $63 million for probable insurance recoveries in connection with the 2022 Mosquito fire, including legal fees. As of December 31, 2023, the Utility also recorded a $8 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 $52 million regulatory asset for costs that were determined to be probable of recovery through the WEMA. See “Regulatory Recovery” below. Loss Recoveries PG&E Corporation and the Utility have recovery mechanisms available for wildfire liabilities including from insurance, customers, and the Wildfire Fund. PG&E Corporation and the Utility recor

SCHEDULE I _ CONDENSED FINANCIA

SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT	12 Months Ended
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT	Dec. 31, 2023
Condensed Financial Information Disclosure [Abstract]
SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT	PG&E CORPORATION SCHEDULE I — CONSOLIDATED FINANCIAL INFORMATION OF PG&E CORPORATION (“PARENT”) CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME Years Ended December 31, (in millions, except per share amounts) 2023 2022 2021 Administrative service revenue $ 154 $ 109 $ 118 Operating expenses (165) (193) (124) Interest income 13 3 — Interest expense (365) (261) (230) Other income (expense) (21) (201) (54) Reorganization items, net — — 1 Equity in earnings of subsidiaries 2,530 2,154 137 Income (loss) before income taxes 2,146 1,611 (152) Income tax benefit (96) (132) (64) Net Income (loss) $ 2,242 $ 1,743 $ (88) Other Comprehensive Income (Loss) Pension and other postretirement benefit plans obligations (net of taxes of $6, $8, and $3, at respective dates) $ (16) $ 21 $ 7 Total other comprehensive income (loss) (16) 21 7 Comprehensive Income (Loss) $ 2,226 $ 1,764 $ (81) Weighted Average Common Shares Outstanding, Basic (1) 2,064 2,235 2,463 Weighted Average Common Shares Outstanding, Diluted (1) 2,138 2,380 2,463 Net earnings (loss) per common share, basic $ 1.09 $ 0.78 $ (0.05) Net earnings (loss) per common share, diluted $ 1.05 $ 0.73 $ (0.05) (1) Includes 0 and 247,743,590 shares of common stock issued to ShareCo as of December 31, 2023 and 2022, respectively. PG&E CORPORATION SCHEDULE I — CONSOLIDATED FINANCIAL INFORMATION OF PG&E CORPORATION (“PARENT”) – (Continued) CONSOLIDATED BALANCE SHEETS Balance at December 31, (in millions) 2023 2022 ASSETS Current Assets Cash and cash equivalents $ 192 $ 125 Restricted cash 3 — Advances to affiliates 24 46 Income taxes receivable 2 10 Other current assets 1 12 Total current assets 222 193 Noncurrent Assets Investments in subsidiaries 36,804 33,021 Other investments 167 160 Deferred income taxes 539 423 Total noncurrent assets 37,510 33,604 Total Assets $ 37,732 $ 33,797 LIABILITIES AND SHAREHOLDERS’ EQUITY Current Liabilities Long-term debt, classified as current — 27 Accounts payable – other 58 88 Income taxes payable 1 — Other current liabilities 363 369 Total current liabilities 422 484 Noncurrent Liabilities Long-term debt 4,599 4,588 Other noncurrent liabilities 141 134 Total noncurrent liabilities 4,740 4,722 Common Shareholders’ Equity Common stock 37,906 36,132 Reinvested earnings (5,322) (7,542) Accumulated other comprehensive income (loss) (14) 1 Total common shareholders’ equity 32,570 28,591 Total Liabilities and Shareholders’ Equity $ 37,732 $ 33,797 PG&E CORPORATION SCHEDULE I – CONSOLIDATED FINANCIAL INFORMATION OF PG&E CORPORATION (“PARENT”) – (Continued) CONSOLIDATED STATEMENTS OF CASH FLOWS (in millions) Year ended December 31, 2023 2022 2021 Cash Flows from Operating Activities: Net income (loss) $ 2,242 $ 1,743 $ (88) Adjustments to reconcile net income to net cash provided by operating activities: Stock-based compensation amortization 4 95 51 Equity in earnings of subsidiaries (2,530) (2,160) (139) Deferred income taxes and tax credits, net (116) (126) (60) Reorganization items, net — — (32) Current income taxes receivable/payable 9 — 2 Other 40 339 81 Net cash used in operating activities (351) (109) (185) Cash Flows From Investing Activities: Investment in subsidiaries (1,290) (994) — Dividends received from subsidiaries (1) 1,775 1,275 — Net cash provided by investing activities 485 281 — Cash Flows From Financing Activities: Proceeds from issuance of convertible notes, net of discount and issuance costs of $27, $0, and $0 at respective dates 2,123 — — Repayment of long-term debt — (28) (28) Proceeds from (repayments of) intercompany note from the Utility — (145) 145 Repayments under term loan credit facilities (2,181) — — Other (6) — (29) Net cash provided by (used in) financing activities (64) (173) 88 Net change in cash, cash equivalents, and restricted cash 70 (1) (97) Cash, cash equivalents, and restricted cash at January 1 125 126 223 Cash, cash equivalents, and restricted cash at December 31 $ 195 $ 125 $ 126 Less: Restricted cash and restricted cash equivalents (3) — — Cash and cash equivalents at December 31 $ 192 $ 125 $ 126 Supplemental disclosures of cash flow information Cash received (paid) for: Interest, net of amounts capitalized $ (309) $ (233) $ (207) Income taxes, net — — 1 Supplemental disclosures of noncash investing and financing activities Changes to PG&E Corporation common stock and treasury stock in connection $ (2,517) $ (2,337) $ 4,854 Common stock dividends declared but not yet paid 21 — — (1) Because of its nature as a holding company, PG&E Corporation classifies dividends received from subsidiaries as an investing cash flow.

SCHEDULE II _ CONSOLIDATED VALU

SCHEDULE II – CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS	12 Months Ended
	Dec. 31, 2023
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
SCHEDULE II – CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS	PG&E CORPORATION SCHEDULE II – CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2023, 2022, and 2021 (in millions) Additions Description Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts Deductions (2) Balance at End of Period Valuation and qualifying accounts deducted from assets: 2023: Allowance for uncollectible accounts (1) $ 166 $ 624 $ — $ 345 $ 445 2022: Allowance for uncollectible accounts (1) $ 171 $ 146 $ — $ 151 $ 166 2021: Allowance for uncollectible accounts (1) $ 146 $ 136 $ — $ 111 $ 171 (1) Allowance for uncollectible accounts is deducted from “Accounts receivable - Customers.” (2) Deductions consist principally of write-offs, net of collections of receivables previously written off. PACIFIC GAS AND ELECTRIC COMPANY SCHEDULE II – CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2023, 2022, and 2021 (in millions) Additions Description Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts Deductions (2) Balance at End of Period Valuation and qualifying accounts deducted from assets: 2023: Allowance for uncollectible accounts (1) $ 166 $ 624 $ — $ 345 $ 445 2022: Allowance for uncollectible accounts (1) $ 171 $ 146 $ — $ 151 $ 166 2021: Allowance for uncollectible accounts (1) $ 146 $ 136 $ — $ 111 $ 171 (1) Allowance for uncollectible accounts is deducted from “Accounts receivable - Customers.” (2) Deductions consist principally of write-offs, net of collections of receivables previously written off.

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended	12 Months Ended
Insider Trading Arrangements	Dec. 31, 2023 shares	Dec. 31, 2023 shares
Cheryl F. Campbell [Member]
Trading Arrangements, by Individual
Material Terms of Trading Arrangement		On December 11, 2023, Patricia K. Poppe, who serves as the Chief Executive Officer of PG&E Corporation and serves on each of PG&E Corporation’s and the Utility’s Boards 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 59,000 shares of PG&E Corporation common stock. The trading arrangement will terminate on the earlier of December 11, 2024 or the execution of the sale of all 59,000 shares.
Patricia K. Poppe [Member]
Trading Arrangements, by Individual
Name	Patricia K. Poppe
Title	Chief Executive Officer
Rule 10b5-1 Arrangement Adopted	true
Adoption Date	December 11, 2023
Rule 10b5-1 Arrangement Terminated	true
Termination Date	December 11, 2024
Arrangement Duration	366 days
Aggregate Available	59,000	59,000

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	Dec. 31, 2023
Accounting Policies [Abstract]
Regulation and Regulated Operations	The Utility follows accounting principles for rate-regulated entities and collects rates from customers to recover “revenue requirements” that have been authorized by the CPUC or the FERC based on the Utility’s cost of providing service. The Utility’s ability to recover a significant portion of its authorized revenue requirements through rates is generally independent, or “decoupled,” from the volume of the Utility’s electricity and natural gas sales. The Utility records assets and liabilities that result from the regulated ratemaking process that would not be recorded under GAAP for nonregulated entities. The Utility capitalizes and records as regulatory assets costs that would otherwise be charged to expense if it is probable that the incurred costs will be recovered through future rates. Regulatory assets are amortized over the future periods in which the costs are recovered. If costs expected to be incurred in the future are currently being recovered through rates, the Utility records those expected future costs as regulatory liabilities. Amounts that are probable of being credited or refunded to customers in the future are also recorded as regulatory liabilities. The Utility also records a regulatory balancing account asset or liability for differences between customer billings and authorized revenue requirements that are probable of recovery or refund. In addition, the Utility records a regulatory balancing account asset or liability for differences between incurred costs and customer billings or authorized revenue meant to recover those costs, to the extent that these differences are probable of recovery or refund. These differences have no impact on net income. See “Revenue Recognition” below. Management continues to believe the use of regulatory accounting is applicable and that all regulatory assets and liabilities are recoverable or refundable. To the extent that portions of the Utility’s operations cease to be subject to cost-of-service rate regulation, or recovery is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are written off.
Cash, Cash Equivalents, and Restricted Cash	Cash and cash equivalents consist of cash and short-term, highly liquid investments with original maturities of three months or less. Cash equivalents are stated at fair value. As of December 31, 2023, the Utility also holds $294 million of restricted cash that primarily consists of AB 1054 and SB 901 fixed recovery charge collections that are to be used to service the associated bonds.
Revenue Recognition	Revenue from Contracts with Customers The Utility recognizes revenues when electricity and natural gas services are delivered. The Utility records unbilled revenues for the estimated amount of energy delivered to customers but not yet billed at the end of the period. Unbilled revenues are included in Accounts receivable on the Consolidated Balance Sheets. Rates charged to customers are based on CPUC and FERC authorized revenue requirements. Revenues can vary significantly from period to period because of seasonality, weather, and customer usage patterns. Regulatory Balancing Account Revenue The CPUC authorizes most of the Utility’s revenues in the Utility’s GRCs, which occur every four years. 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.
Financial Assets Measured at Amortized Cost – Credit Losses	PG&E Corporation and the Utility use the current expected credit loss model to estimate the expected lifetime credit loss on financial assets measured at amortized cost. PG&E Corporation and the Utility evaluate credit risk in their portfolio of financial assets quarterly. As of December 31, 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. Expected credit losses of $636 million, $143 million, and $154 million were recorded in Operating and maintenance expense on the Consolidated Statements of Income for credit losses associated with trade and other receivables during the years ended December 31, 2023, 2022, and 2021, 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 December 31, 2023, the RUBA current balancing accounts receivable balance was $507 million, and CPPMA and FERC noncurrent regulatory asset balances were $5 million and $78 million, respectively. As of December 31, 2022, the RUBA current balancing accounts receivable balance was $126 million, and CPPMA and FERC noncurrent regulatory asset balances were $3 million and $8 million, respectively. Other Receivables and Available-For-Sale Debt Securities Insurance receivables are related to the liability insurance policies PG&E Corporation and the Utility carry. Insurance receivable risk is related to each insurance carrier’s risk of defaulting on their individual policies. Wildfire Fund receivables are the funds available from the statewide fund established under AB 1054 for payment of eligible claims related to the 2021 Dixie fire that exceed $1.0 billion and available insurance coverage. For more information, see Note 14 below. Wildfire Fund receivables risk is related to the Wildfire Fund’s durability, which is a measurement of 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.
Emission Allowances	The Utility purchases GHG emission allowances to satisfy its compliance obligations. Associated costs are recorded as inventory and included in current assets – other and other noncurrent assets – other on the Consolidated Balance Sheets. Costs are carried at weighted-average and are recoverable through rates.
Inventories	Inventories are carried at weighted-average cost and include gas stored underground, fuel oil, materials, and supplies. Natural gas stored underground is recorded to inventory when injected and then expensed as the gas is withdrawn for distribution to customers or to be used as fuel for electric generation. Materials and supplies are recorded to inventory when purchased and expensed or capitalized to plant, as appropriate, when consumed or installed.
Property, Plant, and Equipment	Property, plant, and equipment are reported at the lower of their historical cost less accumulated depreciation or fair value. Historical costs include labor and materials, construction overhead, and AFUDC. See “AFUDC” below. The Utility depreciates property, plant, and equipment using the composite, or group, method of depreciation, in which a single depreciation rate is applied to the gross investment balance in a particular class of property, with the exception of its securitized property, plant and equipment, which is depreciated over the life of the bond and a pattern consistent with principal payments. This method approximates the straight-line method of depreciation over the useful lives of property, plant, and equipment. The Utility’s composite depreciation rates were 3.56% in 2023, 3.74% in 2022, and 3.82% in 2021. The useful lives of the Utility’s property, plant, and equipment are authorized by the CPUC and the FERC, and the depreciation expense is recovered through rates charged to customers. Depreciation expense includes a component for the original cost of assets and a component for estimated cost of future removal, net of any salvage value at retirement. Upon retirement, the original cost of the retired assets, net of salvage value, is charged against accumulated depreciation. The cost of repairs and maintenance, including planned major maintenance activities and minor replacements of property, is charged to Operating and maintenance expense as incurred.
AFUDC	AFUDC represents the estimated cost of debt (i.e., interest) and equity funds used to finance regulated plant additions before they go into service and is capitalized as part of the cost of construction. AFUDC is recoverable through rates over the life of the related property once the property is placed in service. AFUDC related to the cost of debt is recorded as a reduction to interest expense. AFUDC related to the cost of equity is recorded in other income.
Asset Retirement Obligations	PG&E Corporation and the Utility account for an ARO at fair value in the period during which the legal obligation is incurred if a reasonable estimate of fair value and its settlement date can be made. At the time of recording an ARO, the associated asset retirement costs are capitalized as part of the carrying amount of the related long-lived asset. The Utility recognizes a regulatory asset or liability for the timing differences between the recognition of expenses and costs recovered through the ratemaking process. For more information, see Note 3 below. The Utility has not recorded a liability related to certain AROs for assets that are expected to operate in perpetuity. As the Utility cannot estimate a settlement date or range of potential settlement dates for these assets, reasonable estimates of fair value cannot be made. As such, ARO liabilities are not recorded for retirement activities associated with substations, certain hydroelectric facilities; removal of lead-based paint in some facilities and certain communications equipment from leased property; and restoration of land to the conditions under certain agreements. To estimate its liability, the Utility uses a discounted cash flow model based upon significant estimates and assumptions about future decommissioning costs, escalation rates, credit-adjusted risk-free rates, and the estimated date of decommissioning. For generation facilities, the Utility uses a probability-weighted, discounted cash flow model. For nuclear generation facilities, the model also considers multiple decommissioning start-year scenarios. The estimated future cash flows are discounted using a credit-adjusted risk-free rate that reflects the risk associated with the decommissioning obligation. The Utility performs detailed studies of its nuclear generation facilities every three years in conjunction with the NDCTP and updates its nuclear AROs accordingly, unless circumstances warrant more frequent updates, based on its annual evaluation of cost escalation factors and probabilities assigned to various scenarios. The decommissioning cost estimates are based on the plant location and cost characteristics for the Utility’s nuclear power plants. Actual decommissioning costs may vary from these estimates as a result of changes in assumptions such as decommissioning dates; regulatory requirements; technology; and costs of labor, materials, and equipment. The Utility recovers its revenue requirements for decommissioning costs through rates through a non-bypassable charge that the Utility expects will continue until those costs are fully recovered. The ARO liability decreased from $5.9 billion as of December 31, 2022 to $5.5 billion as of December 31, 2023, primarily due to a decrease in nuclear decommissioning and hydroelectric facilities ARO. In the fourth quarter of 2023, the Utility recorded a downward revision to its hydroelectric facilities ARO of $205 million as a result of a revised decommissioning cost estimate. The total nuclear decommissioning obligation was $4.0 billion as of December 31, 2023 compared to $4.1 billion as of December 31, 2022 based on the cost study performed as part of the 2021 NDCTP. As of December 31, 2023, the Utility recorded a $253 million downward adjustment to the nuclear decommissioning ARO to reflect the CPUC’s decision to approve Diablo Canyon’s extended operations until 2030 and the conditional award from the DOE’s Civil Nuclear Credit Program. See “U.S. DOE’s Civil Nuclear Credit Program” below. The Utility’s ARO could be materially impacted if the Utility does not receive the required federal and state licenses, permits, and approvals.
Disallowance of Plant Costs	PG&E Corporation and the Utility record a charge when it is both probable that costs incurred or projected to be incurred for recently completed plant will not be recoverable through rates charged to customers and the amount of disallowance can be reasonably estimated.
Nuclear Decommissioning Obligation and Trusts	The Utility’s nuclear generation facilities consist of two units at Diablo Canyon and the Humboldt Bay independent spent fuel storage installation. Nuclear decommissioning requires the safe removal of a nuclear generation facility from service and the reduction of residual radioactivity to a level that permits termination of the NRC license and release of the property for unrestricted use. The Utility’s nuclear decommissioning costs are recovered through rates and are held in trusts until authorized for release by the CPUC. The Utility classifies its debt investments held in the nuclear decommissioning trusts as available-for-sale. Since the Utility’s nuclear decommissioning trust assets are managed by external investment managers, the Utility does not have the ability to sell its investments at its discretion. Therefore, all unrealized losses are considered other-than-temporary impairments. Gains or losses on the nuclear decommissioning trust investments are refundable to or recoverable from, respectively, customers through rates. Therefore, trust earnings are deferred and included in the regulatory liability for recoveries in excess of the ARO. There is no impact on the Utility’s earnings or accumulated other comprehensive income. The cost of debt and equity securities sold by the trust is determined by specific identification.
Government Assistance	PG&E Corporation and the Utility received various government assistance programs during the years ended December 31, 2023 and 2022. 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. During the years ended December 31, 2023 and 2022, the Consolidated Statements of Income reflected $56 million and $0 million, respectively, recorded as a deduction to Cost of electricity for income related to government grants for incurred eligible costs to purchase nuclear fuel. 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 or when funds expected to be received from the DOE are less than incurred eligible costs to support the extension of Diablo Canyon, the Utility will recognize those forgiven loans as income related to government grants. The Utility records the income related to government grants as a deduction to expense in the same period(s) that eligible costs are incurred. The following table provides a summary of where the DWR loan activity is presented in PG&E Corporation’s and the Utility’s Consolidated Financial Statements: (in millions) 2023 2022 Long-term debt: DWR Loan Outstanding at January 1 $ 312 $ — Proceeds received (1) — 350 Operating Expenses: Operating and maintenance expense - Performance-based disbursements (124) (38) Operating and maintenance expense - Loan forgiven (90) — Total deduction to Operating Expenses (214) (38) Long-term debt: DWR Loan Outstanding at December 31 $ 98 $ 312 (1) On January 11, 2024, the Utility received $233 million in disbursements from the DWR. U.S. DOE’s Civil Nuclear Credit Program On January 11, 2024, the Utility and DOE entered into a Credit Award and Payment Agreement for up to $1.1 billion related to Diablo Canyon as part of the DOE’s Civil Nuclear Credit Program. The Utility will use these funds to repay its loans outstanding under the DWR Loan Agreement (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 a number of factors, including actual costs incurred to extend the Diablo Canyon operations. 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 and will record a receivable related to government grants. During the year ended December 31, 2023, the Consolidated Statements of Income reflected $76 million and $115 million as deductions to Cost of electricity and 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 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 year ended December 31, 2023 or is expected to be provided in the future that was not previously contractually required. As of December 31, 2023 and December 31, 2022, the SPV had net accounts receivable of $2.7 billion and $3.6 billion, respectively, and outstanding borrowings of $1.5 billion 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 year ended December 31, 2023 or is expected to be provided in the future that was not previously contractually required. On November 12, 2021, PG&E Recovery Funding LLC issued approximately $860 million of Senior Secured Recovery Bonds. On November 30, 2022, PG&E Recovery Funding LLC issued approximately $983 million of Series 2022-A Senior Secured Recovery Bonds. As of December 31, 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 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 year ended December 31, 2023 or is expected to be provided in the future that was not previously contractually required. On May 10, 2022, PG&E Wildfire Recovery Funding LLC issued $3.6 billion aggregate principal amount of senior secured recovery bonds (the “Series 2022-A Recovery Bonds”). On July 20, 2022, PG&E Wildfire Recovery Funding LLC issued $3.9 billion aggregate principal amount of senior secured recovery bonds (the “Series 2022-B Recovery Bonds”). As of December 31, 2023 and December 31, 2022, PG&E Wildfire Recovery Funding LLC had outstanding borrowings of $7.3 billion and $7.5 billion, respectively, included in Long-term debt and Long-term debt, classified as current on the 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 December 31, 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 December 31, 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 the issued letter of credit as well as the amounts it pays for base rent and certain costs, per the office lease agreement. For more information, see “Recognition of Lease Assets and Liabilities” below.
Recognition of Lease Assets and Liabilities	A lease exists when an arrangement allows the lessee to control the use of an identified asset for a stated period in exchange for payments. This determination is made at inception of the arrangement. All leases must be recognized as a ROU asset and a lease liability on the balance sheet of the lessee. The ROU asset reflects the lessee’s right to use the underlying asset for the lease term, and the lease liability reflects the obligation to make the lease payments. PG&E Corporation and the Utility have elected not to separate lease and non-lease components. The Utility estimates the ROU assets and lease liabilities at net present value using its incremental secured borrowing rates unless the implicit discount rate in the leasing arrangement can be ascertained. The incremental secured borrowing rate is based on observed market data and other information available at the lease commencement date. The ROU assets and lease liabilities only include the fixed lease payments for arrangements with terms greater than 12 months. These amounts are presented within the supplemental disclosures of noncash activities on the Consolidated Statement of Cash Flows. Renewal and termination options only impact the lease term if it is reasonably certain that they will be exercised. PG&E Corporation recognizes lease expense on a straight-line basis over the lease term. The Utility recognizes lease expense in conformity with ratemaking. Financing Leases
Recently Adopted Accounting Standards and Accounting Standards Issued But Not Yet Adopted	Accounting Standards Issued But Not Yet Adopted Segment Reporting In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures , which amends the existing guidance to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. This ASU will become effective for PG&E Corporation and the Utility for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024, with early adoption permitted. PG&E Corporation and the Utility are currently evaluating the impact the guidance will have on their Consolidated Financial Statements and related disclosures. Income Taxes In December 2023, the FASB issued ASU No. 2023-09 , Income Taxes (Topic 740): Improvements to Income Tax Disclosures, which amends the existing guidance to enhance the transparency and decision usefulness of income tax disclosures. The standard requires consistent categories and greater disaggregation of information in the rate reconciliation, and income taxes paid disaggregated by jurisdiction. This ASU will become effective for PG&E Corporation and the Utility for fiscal years beginning after December 15, 2024. PG&E Corporation and the Utility are currently evaluating the impact the guidance will have on their Consolidated Financial Statements and related disclosures.
Earnings Per Share	PG&E Corporation’s basic EPS is calculated by dividing the income (loss) available for common shareholders by the weighted average number of common shares outstanding. PG&E Corporation applies the treasury stock method of reflecting the dilutive effect of outstanding share-based compensation in the calculation of diluted EPS.
Use of Derivative Instruments	The Utility is exposed to commodity price risk as a result of its electricity and natural gas procurement activities. Procurement costs are recovered through rates. The Utility uses both derivative and non-derivative contracts to manage volatility in customer rates due to fluctuating commodity prices. Derivatives include contracts, such as power purchase agreements, forwards, futures, swaps, options, and CRRs that are traded either on an exchange or over-the-counter. Derivatives are presented in the Utility’s Consolidated Balance Sheets and recorded at fair value and on a net basis in accordance with master netting arrangements for each counterparty. The fair value of derivative instruments is further offset by cash collateral paid or received where the right of offset and the intention to offset exist. Price risk management activities that meet the definition of derivatives are recorded at fair value on the Consolidated Balance Sheets. These instruments are not held for speculative purposes and are subject to certain regulatory requirements. The Utility expects to fully recover through rates all costs related to derivatives under the applicable ratemaking mechanism in place as long as the Utility’s price risk management activities are carried out in accordance with CPUC directives. Therefore, all unrealized gains and losses associated with the change in fair value of these derivatives are deferred and recorded within the Utility’s regulatory assets The Utility elects the normal purchase and sale exception for eligible derivatives. Eligible derivatives are those that require physical delivery in quantities that are expected to be used by the Utility over a reasonable period in the normal course of business, and do not contain pricing provisions unrelated to the commodity delivered. These items are not reflected in the Consolidated Balance Sheets at fair value.

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	Dec. 31, 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: Year Ended December 31, (in millions) 2023 2022 2021 Electric Revenue from contracts with customers Residential $ 6,041 $ 6,130 $ 6,089 Commercial 5,643 5,416 5,042 Industrial 1,784 1,626 1,493 Agricultural 1,413 1,830 1,565 Public street and highway lighting 83 77 73 Other, net (1) 136 (247) (84) Total revenue from contracts with customers - electric 15,100 14,832 14,178 Regulatory balancing accounts (2) 2,324 228 953 Total electric operating revenue $ 17,424 $ 15,060 $ 15,131 Natural gas Revenue from contracts with customers Residential $ 3,686 $ 3,353 $ 2,759 Commercial 1,052 1,005 713 Transportation service only 1,603 1,534 1,346 Other, net (1) (145) 163 140 Total revenue from contracts with customers - gas 6,196 6,055 4,958 Regulatory balancing accounts (2) 808 565 553 Total natural gas operating revenue 7,004 6,620 5,511 Total operating revenues $ 24,428 $ 21,680 $ 20,642 (1) This activity is primarily related to the change in unbilled revenue and amounts subject to refund, partially offset by other miscellaneous revenue items. (2) These amounts represent revenues authorized to be billed or refunded to customers.
Schedule of Estimated Useful Lives and Balances of Utility's Property, Plant and Equipment	The Utility’s estimated service lives of its property, plant, and equipment were as follows: Estimated Service Balance at December 31, (in millions, except estimated service lives) Lives (years) 2023 2022 Electricity generating facilities (1) 3 to 75 $ 11,423 $ 11,781 Electricity distribution facilities 10 to 70 45,205 41,061 Electricity transmission facilities 15 to 75 17,562 16,413 Natural gas distribution facilities 20 to 60 16,324 15,366 Natural gas transmission and storage facilities 5 to 70 10,496 9,859 General plant and other 5 to 50 9,165 8,518 Financing lease 787 18 Construction work in progress 4,452 4,137 Total property, plant, and equipment 115,414 107,153 Accumulated depreciation (33,093) (30,946) Net property, plant, and equipment (2) $ 82,321 $ 76,207 (1) Balance includes nuclear fuel inventories. Nuclear generating facilities have been authorized by the CPUC to be fully depreciated by December 31, 2025. Stored nuclear fuel inventory is stated at weighted-average cost. Nuclear fuel in the reactor is expensed as it is used based on the amount of energy output. See Note 15 below. (2) Includes $1.7 billion of fire risk mitigation-related property, plant, and equipment securitized in accordance with AB 1054.
Changes In Asset Retirement Obligations	The following table summarizes the changes in ARO liability during 2023 and 2022, including nuclear decommissioning obligations: (in millions) 2023 2022 ARO liability at beginning of year $ 5,912 $ 5,298 Liabilities incurred — 134 Revision in estimated cash flows (585) 325 Accretion 253 213 Liabilities settled (68) (58) ARO liability at end of year $ 5,512 $ 5,912
Schedule Of Government Assistance	The following table provides a summary of where the DWR loan activity is presented in PG&E Corporation’s and the Utility’s Consolidated Financial Statements: (in millions) 2023 2022 Long-term debt: DWR Loan Outstanding at January 1 $ 312 $ — Proceeds received (1) — 350 Operating Expenses: Operating and maintenance expense - Performance-based disbursements (124) (38) Operating and maintenance expense - Loan forgiven (90) — Total deduction to Operating Expenses (214) (38) Long-term debt: DWR Loan Outstanding at December 31 $ 98 $ 312 (1) On January 11, 2024, the Utility received $233 million in disbursements from the DWR.
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income	The changes, net of income tax, in PG&E Corporation’s accumulated other comprehensive income (loss) for the year ended December 31, 2023 consisted of the following: (in millions, net of income tax) Pension Other Customer Credit Trust Total Beginning balance $ (12) $ 18 $ (6) $ — Other comprehensive income before reclassifications: Unrealized gain on investments (net of taxes of $0, $0 and $3, respectively) — — 8 8 Unrecognized net actuarial gain (loss) (net of taxes of $76, $28 and $0, respectively) (196) 73 — (123) Regulatory account transfer (net of taxes of $70, $28 and $0, respectively) 180 (73) — 107 Amounts reclassified from other comprehensive income: Amortization of prior service cost (credit) (net of taxes of $1, $1 and $0, respectively) (1) (3) 2 — (1) Amortization of net actuarial (gain) loss (net of taxes of $0, $5 and $0, respectively) (1) 1 (14) — (13) Regulatory account transfer (net of taxes of $1, $4 and $0, respectively) (1) 2 12 — 14 Net current period other comprehensive income (loss) (16) — 8 (8) Ending balance $ (28) $ 18 $ 2 $ (8) (1) These components are included in the computation of net periodic pension and other postretirement benefit costs. See Note 12 below for additional details. The changes, net of income tax, in PG&E Corporation’s accumulated other comprehensive income (loss) for the year ended December 31, 2022 consisted of the following: (in millions, net of income tax) Pension Other Customer Credit Trust Total Beginning balance $ (33) $ 18 $ — $ (15) Other comprehensive income before reclassifications: Unrealized loss on investments (net of taxes of $0, $0 and $3, respectively) — — (6) (6) Unrecognized net actuarial gain (loss) (net of taxes of $102, $99 and $0, respectively) 263 (255) — 8 Regulatory account transfer (net of taxes of $94, $99 and $0, respectively) (242) 255 — 13 Amounts reclassified from other comprehensive income: Amortization of prior service cost (credit) (net of taxes of $1, $2 and $0, respectively) (1) (3) 5 — 2 Amortization of net actuarial (gain) loss (net of taxes of $1, $11 and $0, respectively) (1) 1 (29) — (28) Regulatory account transfer (net of taxes of $0, $9 and $0, respectively) (1) 2 24 — 26 Net current period other comprehensive income (loss) 21 — (6) 15 Ending balance $ (12) $ 18 $ (6) $ — (1) These components are included in the computation of net periodic pension and other postretirement benefit costs. See Note 12 below for additional details.
Schedule of Lease Expense	The following table shows the lease cost recognized for the fixed and variable component of the Utility’s lease obligations: Year Ended December 31, (in millions) 2023 Financing lease fixed cost: Amortization of ROU assets $ 115 Interest on lease liabilities 27 Financing lease variable cost 3 Total financing lease costs $ 145 The following table shows the lease cost recognized for the fixed and variable component of the Utility’s lease obligations: Year Ended December 31, (in millions) 2023 2022 Operating lease fixed cost $ 269 $ 500 Operating lease variable cost 1,632 1,829 Total operating lease costs $ 1,901 $ 2,329
Schedule of Future Expected Operating Lease Payments	At December 31, 2023, the Utility’s future expected financing lease payments were as follows: (in millions) December 31, 2023 2024 $ 305 2025 531 2026 44 2027 — 2028 — Total lease payments 880 Less imputed interest (67) Total $ 813 At December 31, 2023, the Utility’s future expected operating lease payments were as follows: (in millions) December 31, 2023 2024 $ 116 2025 115 2026 112 2027 110 2028 97 Thereafter 256 Total lease payments 806 Less imputed interest (208) Total $ 598

REGULATORY ASSETS, LIABILITIE_2

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Tables)	12 Months Ended
	Dec. 31, 2023
Regulated Operations [Abstract]
Long-Term Regulatory Assets	Noncurrent regulatory assets are comprised of the following: Balance at December 31, Recovery (in millions) 2023 2022 Pension benefits (1) $ 348 $ 120 Indefinitely Environmental compliance costs 1,218 1,193 32 years Utility retained generation (2) 39 86 4 years Price risk management 160 177 16.5 years Catastrophic event memorandum account (3) 1,074 1,085 1 - 3 years Wildfire expense memorandum account (4) 540 439 TBD years Fire hazard prevention memorandum account (5) 7 79 1 - 2 years Fire risk mitigation memorandum account (6) 110 65 1 - 3 years Wildfire mitigation plan memorandum account (7) 541 756 1 - 3 years Deferred income taxes (8) 3,543 2,730 51 years Insurance premium costs (9) 1 99 2 - 4 years Wildfire mitigation balancing account (10) 120 327 1 - 4 years Vegetation management balancing account (11) 1,538 2,276 1 - 3 years COVID-19 pandemic protection memorandum accounts (12) 17 26 1 - 3 years Microgrid memorandum account (13) 59 213 1 - 3 years Financing costs (14) 196 211 Various SB 901 securitization (15) 5,249 5,378 30 years AROs in excess of recoveries (16) 73 120 Various General rate case memorandum accounts (17) 1,291 — 1 - 2 years Other 1,065 1,063 Various Total noncurrent regulatory assets $ 17,189 $ 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. As of December 31, 2023 and 2022, $43 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 were approved for recovery in the 2020 WMCE final decision. (6) Includes incremental costs associated with fire risk mitigation not included in the WMP’s. Recovery of costs incurred during the period from 2020 through 2022 was requested in the 2023 WGSC application, and costs incurred in 2023 will be requested in a future application. Recovery of FRMMA costs is subject to CPUC review and approval. (7) Includes costs incurred in 2020 through 2023 and associated with each year’s respective approved WMP. Recovery of costs incurred during the period from 2020 through 2022 was requested in the 2023 WGSC application, and costs incurred in 2023 will be requested in a future application. Also includes the noncurrent portion of costs associated with the 2019 WMP that were approved for recovery in 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, respectively. (10) Represents costs associated with certain wildfire mitigation activities for the period of January 1, 2020 through December 31, 2022 . The noncurrent balance includes costs incurred during the 12-month period ending December 31, 2020 that were approved for recovery in the 2021 WMCE final decision. The remaining balance includes costs above 115% of adopted revenue requirements, as authorized in the 2020 GRC rate case, 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 December 31, 2022. The noncurrent balance represents costs above 120% of adopted revenue requirements, as authorized in the 2020 GRC rate case, 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 December 31, 2023, the Utility had recorded uncollectibles in the amount of $5 million for small business customers. The remaining $12 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 residential customers pending approval for recovery in the RUBA in addition to uncollectibles recorded 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, Regulated Operations more than twelve months from the current date. These costs and their amortization periods 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 will be 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 11 below. Recovery periods for this balance vary because the different sites and assets to which the ARO expenses are attributable have different recovery periods. (17) The GRC memorandum accounts record the difference between the gas and electric revenue requirements in effect on January 1, 2023 and through the date of the final 2023 GRC decision as authorized by the CPUC in December 2023. These amounts will be recovered in rates over 24 months, beginning January 1, 2024.
Long-Term Regulatory Liabilities	Noncurrent regulatory liabilities are comprised of the following: Balance at December 31, (in millions) 2023 2022 Cost of removal obligations (1) $ 8,191 $ 7,773 Public purpose programs (2) 1,238 1,062 Employee benefit plans (3) 1,032 904 Transmission tower wireless licenses (4) 384 430 SFGO sale (5) 185 264 SB 901 securitization (6) 6,628 5,800 Wildfire self-insurance (7) 407 — Other 1,379 1,397 Total noncurrent regulatory liabilities $ 19,444 $ 17,630 (1) Represents the cumulative differences between the recorded costs to remove assets and amounts collected through 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 through 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. Of the $384 million, $288 million will be refunded to FERC-jurisdictional customers through 2042, and $96 million will be refunded to CPUC-jurisdictional customers through 2026. (5) Represents the noncurrent portion of the net gain on the sale of the SFGO, which is being 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. See Note 5 below. (7) Represents amounts collected through rates designated for wildfire self-insurance. See Note 14 below.
Current Regulatory Balancing Accounts Receivable	Current regulatory balancing accounts receivable and payable are comprised of the following: Receivable (in millions) 2023 2022 Electric distribution (1) $ 1,092 $ 448 Electric transmission (2) 99 96 Gas distribution and transmission (3) 144 72 Energy procurement (4) 1,002 684 Public purpose programs (5) 137 358 Fire hazard prevention memorandum account (6) 40 — Wildfire mitigation plan memorandum account (7) 161 — Wildfire mitigation balancing account (8) 12 2 Vegetation management balancing account (9) 340 137 Insurance premium costs (10) 227 602 Residential uncollectibles balancing accounts (11) 507 126 Catastrophic event memorandum account (12) 413 144 General rate case memorandum accounts (13) 1,097 — Other 389 595 Total regulatory balancing accounts receivable $ 5,660 $ 3,264
Current Regulatory Balancing Accounts Payable	Payable (in millions) 2023 2022 Electric transmission (2) $ 200 $ 228 Gas distribution and transmission (3) 224 66 Energy procurement (4) 77 428 Public purpose programs (5) 299 272 SFGO sale 79 152 Wildfire mitigation balancing account (8) 125 — Nuclear decommissioning adjustment mechanism (14) 216 8 Other 449 504 Total regulatory balancing accounts payable $ 1,669 $ 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 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 which were 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 which were authorized for cost recovery in the 2021 WMCE proceeding and the final decision granting interim rate relief in connection with the 2022 WMCE application. (9) The VMBA tracks routine and enhanced vegetation management activities which were approved for cost recovery in the final decision granting interim rate relief in connection with the 2022 WMCE application. (10) The insurance premium costs accounts 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, respectively. In addition to insurance premium costs recorded in Regulatory balancing accounts receivable and in noncurrent Regulatory assets above, as of December 31, 2023, and 2022 there were $0 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. The RUBA balance increased from December 31, 2022 to December 31, 2023 due to additional under-collections from residential customers, which are expected to be recovered in 2024. (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 which were approved for cost recovery in the 2018 CEMA and 2020 WMCE final decisions. (13) The GRC memorandum accounts track the difference between the revenue requirements in effect on January 1, 2023 and the revenue requirements authorized by the CPUC in the 2023 GRC final decision in December 2023. (14) The Nuclear decommissioning adjustment mechanism (“NDAM”) account tracks the collection of revenue requirements associated with the decommissioning of the Utility’s nuclear facilities which were approved in the 2021 NDCTP final decision. See Note 2 above.

DEBT (Tables)

DEBT (Tables)	12 Months Ended
DEBT (Tables)	Dec. 31, 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 at December 31, 2023: (in millions) Termination Maximum Facility Limit Loans Outstanding Letters of Credit Outstanding Facility Utility revolving credit facility June 2028 $ 4,400 (1) $ (1,750) $ (652) $ 1,998 Utility Receivables Securitization Program (2) June 2025 1,499 (3) (1,499) — — (3) PG&E Corporation revolving credit facility June 2026 500 — — 500 Total credit facilities $ 6,399 $ (3,249) $ (652) $ 2,498 (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.
Schedule of Long-term Debt	The following table summarizes PG&E Corporation’s and the Utility’s long-term debt: Balance at (in millions) Contractual Interest Rates December 31, 2023 December 31, 2022 PG&E Corporation Term Loan - Stated Maturity: 2027 (1) variable rate (2) $ 500 $ 2,681 Convertible Notes due 2027 4.25% 2,150 — Senior Secured Notes due 2028 5.00% 1,000 1,000 Senior Secured Notes due 2030 5.25% 1,000 1,000 Less: current portion, net of unamortized discount and debt issuance costs — (28) Unamortized discount and debt issuance costs, net (51) (66) Total PG&E Corporation Long-Term Debt 4,599 4,587 Utility First Mortgage Bonds - Stated Maturity: 2023 1.70% - 4.25% — 2,075 2024 3.40% - 3.75% 800 1,800 2025 3.45% - 4.95% 1,925 1,925 2026 2.95% - 3.15% 2,551 2,551 2027 2.10% - 5.45% 3,000 3,000 2028 3.00% - 4.65% 1,975 1,975 2029 4.20% - 6.10% 1,250 400 2030 4.55% 3,100 3,100 2031 2.50% - 3.25% 3,000 3,000 2032 4.40% - 5.90% 1,050 1,050 2033 6.15% - 6.40% 1,900 — 2034 6.95% 800 — 2040 3.30% - 4.50% 2,951 2,951 2041 4.20% - 4.50% 700 700 2042 3.75% - 4.45% 750 750 2043 4.60% 375 375 2044 4.75% 675 675 2045 4.30% 600 600 2046 4.00% - 4.25% 1,050 1,050 2047 3.95% 850 850 2050 3.50% - 4.95% 5,025 5,025 2052 5.25% 550 550 2053 6.70% - 6.75% 2,000 — Less: current portion, net of unamortized discount and debt issuance costs (800) (2,072) Unamortized discount, premium and debt issuance costs, net (246) (195) Total Utility First Mortgage Bonds 35,831 32,135 Recovery Bonds (3) 9,124 9,292 Less: current portion (176) (168) DWR Loan (4) 98 312 Credit Facilities Receivables Securitization Program - Stated Maturity: 2025 variable rate (5) 1,499 1,184 2-Year Term Loan - Stated Maturity: 2024 variable rate (6) 400 400 Less: current portion (400) — Total Utility Long-Term Debt 46,376 43,155 Total PG&E Corporation Consolidated Long-Term Debt $ 50,975 $ 47,742 (1) On December 8, 2023, PG&E Corporation amended its existing term loan agreement to, among other things, extend the maturity date from June 23, 2025 to June 23, 2027. (2) At December 31, 2023, the contractual London Interbank Offered Rate (“LIBOR”)-based interest rate on the term loan was 7.85% and at December 31, 2022, the contractual Secured Overnight Financing Rate (“SOFR”)-based interest rate on the term loan was 7.44%. (3) The amount includes bonds related to AB 1054 and SB 901 securitization transactions. For AB 1054 interest rates, see the 2021 Form 10-K and 2022 Form 10-K. For SB 901 interest rates, see the 2022 Form 10-K. (4) The Utility is not required to pay interest on the DWR loan, see Note 2 - Government Assistance. (5) At December 31, 2023 and 2022, the contractual SOFR-based interest rate on the Receivables Securitization Program was 6.75% and 5.10%, respectively. (6) At December 31, 2023 and 2022, the contractual SOFR-based interest rate on the term loan was 6.60% and 5.71%, respectively.
Schedule Of Long Term Debt Repayments	PG&E Corporation’s and the Utility’s combined stated long-term debt principal repayment amounts at December 31, 2023 are reflected in the table below: (in millions, except interest rates) 2024 2025 2026 2027 2028 Thereafter Total PG&E Corporation Average fixed interest rate — % — % — % 4.25 % 5.00 % 5.25 % 4.67 % Fixed rate obligations $ — $ — $ — $ 2,150 $ 1,000 $ 1,000 $ 4,150 Variable interest rate as of December 31, 2023 — % — % — % 7.85 % — % — % 7.85 % Variable rate obligations $ — $ — $ — $ 500 $ — $ — $ 500 Utility (1) Average fixed interest rate 3.60 % 3.82 % 3.10 % 3.22 % 3.58 % 4.66 % 4.31 % Fixed rate obligations $ 800 $ 1,925 $ 2,551 $ 3,000 $ 1,975 $ 26,626 $ 36,877 Variable interest rate as of December 31, 2023 6.60 % 6.75 % — % — % — % — % 6.72 % Variable rate obligations $ 400 $ 1,499 $ — $ — $ — $ — $ 1,899 Recovery Bonds (2) AB 1054 obligations $ 46 $ 48 $ 50 $ 51 $ 53 $ 1,539 $ 1,787 SB 901 obligations 130 135 141 146 152 6,634 7,338 Total consolidated debt $ 1,376 $ 3,607 $ 2,742 $ 5,847 $ 3,180 $ 35,799 $ 52,551 (1) The balance excludes DWR loan, see Note 2 - Government Assistance. (2) Recovery bonds were issued by, and are repayment obligations of, consolidated VIEs. For AB 1054 interest rates, see the 2021 Form 10-K and 2022 Form 10-K. For SB 901 interest rates, see the 2022 Form 10-K.

SB 901 SECURITIZATION AND CUS_2

SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST (Tables)	12 Months Ended
SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST (Tables)	Dec. 31, 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 (129) Balance at December 31, 2023 $ 5,249 SB 901 securitization regulatory liability (in millions) Balance at December 31, 2022 $ (5,800) Amortization 451 Additions (1) (1,279) Balance at December 31, 2023 $ (6,628) (1) Includes $12 million of expected returns on investments in the customer credit trust to be credited to customers.

COMMON STOCK AND SHARE-BASED _2

COMMON STOCK AND SHARE-BASED COMPENSATION (Tables)	12 Months Ended
COMMON STOCK AND SHARE-BASED COMPENSATION (Tables)	Dec. 31, 2023
Common Stock And Share-Based Compensation [Abstract]
Schedule of Compensation Expense for Share-based Incentive Awards	The following table provides a summary of total share-based compensation expense recognized by PG&E Corporation for share-based incentive awards for 2023: (in millions) 2023 2022 2021 Restricted stock units 64 60 35 Performance shares 27 55 21 Total compensation expense (pre-tax) $ 91 $ 115 $ 56 Total compensation expense (after-tax) $ 65 $ 83 $ 40
Summary of Stock Option Activity	The following table summarizes stock option activity for PG&E Corporation and the Utility for 2023: Number of Weighted Average Grant- Weighted Average Remaining Contractual Term Aggregate Intrinsic Value Outstanding at January 1 2,152,132 $ 7.36 $ — Granted (1) — — — Exercised — — — Forfeited or expired (755,871) 5.80 — Outstanding at December 31 1,396,261 8.20 2.29 — Vested or expected to vest at December 31 1,396,261 8.20 2.29 — Exercisable at December 31 1,396,261 $ 8.20 2.29 $ — (1) Represents additional payout of existing stock option grants.
Schedule of Restricted Stock Units	The following table summarizes restricted stock unit activity for 2023: Number of Weighted Average Grant- Nonvested at January 1 10,978,120 $ 11.21 Granted 4,337,632 15.70 Vested (5,710,073) 11.16 Forfeited (337,254) 12.77 Nonvested at December 31 9,268,425 $ 13.29
Schedule of Performance Shares	The following table summarizes activity for performance shares in 2023: Number of Weighted Average Grant- Nonvested at January 1 11,022,054 $ 10.68 Granted 4,881,031 13.39 Vested (8,049,294) 9.16 Forfeited (1,251,499) 13.2 Nonvested at December 31 6,602,292 $ 14.06

EARNINGS PER SHARE (Tables)

EARNINGS PER SHARE (Tables)	12 Months Ended
EARNINGS PER SHARE (Tables)	Dec. 31, 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 (loss) available for common shareholders and weighted average common shares outstanding for calculating diluted EPS for 2023, 2022, and 2021. Year Ended December 31, (in millions, except per share amounts) 2023 2022 2021 Income (loss) available for common shareholders $ 2,242 $ 1,800 $ (102) Weighted average common shares outstanding, basic 2,064 1,987 1,985 Add incremental shares from assumed conversions: Employee share-based compensation 6 8 — Equity Units 68 137 — Weighted average common shares outstanding, diluted 2,138 2,132 1,985 Total earnings (loss) per common share, diluted $ 1.05 $ 0.84 $ (0.05)

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
INCOME TAXES (Tables)	Dec. 31, 2023
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	The significant components of income tax provision (benefit) by taxing jurisdiction were as follows: PG&E Corporation Utility Year Ended December 31, (in millions) 2023 2022 2021 2023 2022 2021 Current: Federal $ (1) $ (1) $ — $ (1) $ (1) $ — State — — 1 — — — Deferred: Federal (1,047) (943) 543 (981) (852) 588 State (507) (389) 296 (477) (348) 316 Tax credits (2) (5) (4) (2) (5) (4) Income tax provision (benefit) $ (1,557) $ (1,338) $ 836 $ (1,461) $ (1,206) $ 900
Schedule of Deferred Tax Assets and Liabilities	The following tables describe net deferred income tax assets and liabilities: PG&E Corporation Utility Year Ended December 31, (in millions) 2023 2022 2023 2022 Deferred income tax assets: Tax carryforwards $ 9,132 $ 7,156 $ 8,740 $ 6,868 Compensation 145 157 82 80 GHG allowance 361 239 361 239 Wildfire-related claims (1) 1,069 1,489 1,069 1,489 Operating lease liability 142 368 142 368 Transmission tower wireless licenses 250 254 250 254 Bad debt 134 55 134 55 Other (2) 130 142 109 122 Total deferred income tax assets $ 11,363 $ 9,860 $ 10,887 $ 9,475 Deferred income tax liabilities: Property-related basis differences 10,058 9,374 10,047 9,363 Regulatory balancing accounts 1,433 1,376 1,433 1,376 Debt financing costs 428 465 428 465 Operating lease ROU asset 142 368 142 368 Income tax regulatory asset (3) 991 764 991 764 Environmental reserve 200 163 200 163 Other (4) 91 82 82 67 Total deferred income tax liabilities $ 13,343 $ 12,592 $ 13,323 $ 12,566 Total net deferred income tax liabilities $ 1,980 $ 2,732 $ 2,436 $ 3,091 (1) Amounts primarily relate to wildfire-related claims, net of estimated insurance recoveries, and legal and other costs related to various wildfires that have occurred in PG&E Corporation’s and the Utility’s service area over the past several years. (2) Amounts include benefits, state taxes, and customer advances for construction. (3) Represents the tax gross up portion of the deferred income tax for the cumulative differences between amounts recognized for ratemaking purposes and amounts recognized for tax, including the impact of changes in net deferred taxes associated with a lower federal income tax rate as a result of the TCJA. (4) Amounts primarily include property taxes and prepaid expense.
Schedule of Effective Income Tax Rate Reconciliation	The following table reconciles income tax expense at the federal statutory rate to the income tax provision: PG&E Corporation Utility Year Ended December 31, 2023 2022 2021 2023 2022 2021 Federal statutory income tax rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) in income tax rate resulting from: State income tax (net of federal benefit) (1) (57.9) (75.8) 31.3 (34.4) (26.9) 24.1 Effect of regulatory treatment of fixed asset differences (2) (63.4) (123.8) (71.5) (40.1) (49.2) (51.6) Tax credits (2.2) (3.2) (1.7) (2.2) (1.3) (1.2) Fire Victim Trust (3) (126.9) (160.9) 127.3 (80.2) (64.0) 91.9 Other, net (4) 2.2 12.9 5.3 1.1 2.2 2.6 Effective tax rate (227.2) % (329.8) % 111.7 % (134.8) % (118.2) % 86.8 % (1) Includes the effect of state flow-through ratemaking treatment. (2) Includes the effect of federal flow-through ratemaking treatment for certain property-related costs. For these temporary tax differences, PG&E Corporation and the Utility recognize the deferred tax impact in the current period and record offsetting regulatory assets and liabilities. Therefore, PG&E Corporation’s and the Utility’s effective tax rates are impacted as these differences arise and reverse. PG&E Corporation and the Utility recognize such differences as regulatory assets or liabilities as it is probable that these amounts will be recovered from or returned to customers in future rates. In 2023, 2022, and 2021, the amounts also reflect the impact of the amortization of excess deferred tax benefits to be refunded to customers as a result of the TCJA passed in December 2017. (3) Includes an adjustment for the tax benefit of the sale of shares by the Fire Victim Trust in 2023 and 2022 and a DTA write-off associated with the grantor trust election for the Fire Victim Trust in 2021. (4) These amounts primarily represent the impact of tax audit settlements and non-tax deductible penalty costs.
Schedule of Change in Unrecognized Tax Benefits	The following table reconciles the changes in unrecognized tax benefits: PG&E Corporation Utility (in millions) 2023 2022 2021 2023 2022 2021 Balance at beginning of year $ 570 $ 498 $ 437 $ 570 $ 498 $ 437 Additions for tax position taken during a prior year 1 — — 1 — — Reductions for tax position taken during a prior year — (1) (23) — (1) (23) Additions for tax position taken during the current year 45 73 85 45 73 85 Settlements — — (1) — — (1) Balance at end of year $ 616 $ 570 $ 498 $ 616 $ 570 $ 498
Schedule of Operating Loss and Tax Credit Carryforward Balances	The following table describes PG&E Corporation’s operating loss and tax credit carryforward balances: (in millions) December 31, 2023 Expiration Federal: Net operating loss carryforward - Pre-2018 $ 3,447 2031 - 2036 Net operating loss carryforward - Post-2017 29,403 N/A Tax credit carryforward 175 2029 - 2041 State: Net operating loss carryforward $ 32,583 2039 - 2041 Tax credit carryforward 137 Various

DERIVATIVES (Tables)

DERIVATIVES (Tables)	12 Months Ended
DERIVATIVES (Tables)	Dec. 31, 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 December 31, 2023 December 31, 2022 Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 196,063,296 171,212,813 Options 30,695,000 27,785,000 Electricity (MWh) Forwards, Futures and Swaps 9,169,967 10,814,728 Options 92,400 215,600 Congestion Revenue Rights (3) 170,465,674 205,743,505 (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 December 31, 2023, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 134 $ (8) $ 50 $ 176 Other noncurrent assets – other 280 — — 280 Current liabilities – other (172) 8 46 (118) Noncurrent liabilities – other (160) — — (160) Total commodity risk $ 82 $ — $ 96 $ 178 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 December 31, 2023, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 134 $ (8) $ 50 $ 176 Other noncurrent assets – other 280 — — 280 Current liabilities – other (172) 8 46 (118) Noncurrent liabilities – other (160) — — (160) Total commodity risk $ 82 $ — $ 96 $ 178 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)	12 Months Ended
FAIR VALUE MEASUREMENTS (Tables)	Dec. 31, 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 December 31, 2023 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 203 $ — $ — $ — $ 203 Nuclear decommissioning trusts Short-term investments 52 — — — 52 Global equity securities 2,144 — — — 2,144 Fixed-income securities 1,168 909 — — 2,077 Assets measured at NAV — — — — 18 Total nuclear decommissioning trusts (2) 3,364 909 — — 4,291 Customer credit trust Short-term investments 49 — — — 49 Global equity securities 71 — — — 71 Fixed-income securities 29 84 — — 113 Total customer credit trust 149 84 — — 233 Price risk management instruments (Note 10) Electricity — 7 404 (1) 410 Gas — 3 — 43 46 Total price risk management instruments — 10 404 42 456 Rabbi trusts Short-term investments 102 — — — 102 Global equity securities 5 — — — 5 Life insurance contracts — 65 — — 65 Total rabbi trusts 107 65 — — 172 Long-term disability trust Short-term investments 7 — — — 7 Assets measured at NAV — — — — 139 Total long-term disability trust 7 — — — 146 TOTAL ASSETS $ 3,830 $ 1,068 $ 404 $ 42 $ 5,501 Liabilities: Price risk management instruments (Note 10) Electricity $ — $ 43 $ 213 $ (6) $ 250 Gas — 76 — (48) 28 TOTAL LIABILITIES $ — $ 119 $ 213 $ (54) $ 278 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and cash collateral. (2) Represents amount before deducting $717 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 10) 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 10) 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 December 31, 2023 Valuation Unobservable Fair Value Measurement Assets Liabilities Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 357 $ 134 Market approach CRR auction prices $ (923.72) - 16,696.90 / 1.43 Power purchase agreements $ 47 $ 79 Discounted cash flow Forward prices $ 0.86 - 189.80 / 60.03 (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 years ended December 31, 2023 and 2022, respectively: 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) (8) 233 Asset balance as of December 31 $ 191 $ 199 (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 December 31, 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 (1) $ 4,548 $ 4,695 $ 4,355 $ 4,490 Utility 35,909 32,866 32,847 27,666 (1) As of December 31, 2023, the net carrying amount and the estimated fair value (Level 2) of the Convertible Notes were $2.1 billion and $2.2 billion, respectively.
Schedule of Unrealized Gains (Losses) Related to Available-for-sale Investments	The following table provides a summary of equity securities and available-for-sale debt securities: (in millions) Amortized Total Total Total Fair As of December 31, 2023 Nuclear decommissioning trusts Short-term investments $ 52 $ — $ — $ 52 Global equity securities 381 1,792 (11) 2,162 Fixed-income securities 2,103 60 (86) 2,077 Total (1) $ 2,536 $ 1,852 $ (97) $ 4,291 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 $717 million and $575 million as of December 31, 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) December 31, 2023 Less than 1 year $ 9 1–5 years 665 5–10 years 463 More than 10 years 940 Total maturities of fixed-income securities $ 2,077 The following table provides a summary of equity securities and available-for-sale debt securities: (in millions) Amortized Total Total Total Fair As of December 31, 2023 Customer credit trust Short-term investments $ 49 $ — $ — $ 49 Global equity securities 56 16 (1) 71 Fixed-income securities 111 2 — 113 Total $ 216 $ 18 $ (1) $ 233 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: (in millions) 2023 2022 2021 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 2,235 $ 3,316 $ 1,678 Gross realized gains on securities 80 2 286 Gross realized losses on securities (74) (3) (19) The fair value of fixed-income securities by contractual maturity is as follows: As of (in millions) December 31, 2023 Less than 1 year $ — 1–5 years 25 5–10 years 29 More than 10 years 59 Total maturities of fixed-income securities $ 113 The following table provides a summary of activity for the fixed-income and equity securities: (in millions) 2023 2022 Proceeds from sales and maturities of customer credit trust investments $ 556 $ 250 Gross realized gains on securities 23 10 Gross realized losses on securities (1) (19) (41) (1) Includes $4 million and $6 million of impaired debt securities which were written down to their respective fair values during the year ended December 31, 2023 and the year ended December 31, 2022, respectively.

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	12 Months Ended
EMPLOYEE BENEFIT PLANS (Tables)	Dec. 31, 2023
Employee Benefit and Share-Based Payment Arrangement, Noncash Expense [Abstract]
Reconciliation of Changes in Plan Assets Benefit Obligations and Funded Status	The following tables show the reconciliation of changes in plan assets, benefit obligations, and the plans’ aggregate funded status for pension benefits and other benefits for PG&E Corporation during 2023 and 2022: Pension Plan (in millions) 2023 2022 Change in plan assets: Fair value of plan assets at beginning of year $ 16,369 $ 21,895 Actual return on plan assets 1,518 (4,916) Company contributions 336 339 Benefits and expenses paid (1,012) (949) Fair value of plan assets at end of year $ 17,211 $ 16,369 Change in benefit obligation: Benefit obligation at beginning of year $ 16,608 $ 22,759 Service cost for benefits earned 379 575 Interest cost 913 692 Actuarial loss (gain) (1) 809 (6,471) Plan amendments — — Benefits and expenses paid (1,012) (947) Benefit obligation at end of year (2) $ 17,697 $ 16,608 Funded Status: Current liability $ (9) $ (8) Noncurrent liability (477) (231) Net liability at end of year $ (486) $ (239) (1) The actuarial loss for the year ended December 31, 2023 was due to a decrease in the discount rate used to measure the projected benefit obligation and unfavorable changes in the demographic assumptions; the actuarial gain for the year ended December 31, 2022 was due to an increase in the discount rate used to measure the projected benefit obligation, offset by unfavorable changes in the demographic assumptions. (2) PG&E Corporation’s accumulated benefit obligation was $16.3 billion and $15.4 billion at December 31, 2023 and 2022, respectively. Postretirement Benefits Other than Pensions (in millions) 2023 2022 Change in plan assets: Fair value of plan assets at beginning of year $ 2,336 $ 3,102 Actual return on plan assets 260 (693) Company contributions 5 26 Plan participant contribution 81 81 Benefits and expenses paid (183) (180) Fair value of plan assets at end of year $ 2,499 $ 2,336 Change in benefit obligation: Benefit obligation at beginning of year $ 1,339 $ 1,766 Service cost for benefits earned 38 62 Interest cost 73 53 Actuarial loss (gain) (1) 8 (486) Benefits and expenses paid (165) (162) Federal subsidy on benefits paid 3 3 Plan participant contributions 81 81 Voluntary separation program-related termination benefits (2) — 22 Benefit obligation at end of year $ 1,377 $ 1,339 Funded Status: (3) Noncurrent asset $ 1,122 $ 997 Noncurrent liability — — Net asset at end of year $ 1,122 $ 997 (1) The actuarial loss for the year ended December 31, 2023 was primarily due to a decrease in the discount rate used to measure the accumulated benefit obligations, offset by favorable changes in claims cost and demographic assumptions. The actuarial gain for the year ended December 31, 2022 was primarily due to an increase in the discount rate used to measure the accumulated benefit obligations, offset by unfavorable changes in demographic assumptions. (2) Represents voluntary separation program related credits to employee retirement health savings accounts. See “Voluntary Separation Program” in Note 3 of the Notes to the Consolidated Financial Statements in Item 8 of the 2022 Form 10-K. (3) At December 31, 2023 and 2022, the postretirement medical plan and the postretirement life insurance plan were in overfunded positions. The projected benefit obligation and the fair value of plan assets for the postretirement life insurance plan were $275 million and $292 million as of December 31, 2023, and $259 million and $266 million as of December 31, 2022, respectively.
Components of Net Periodic Benefit Cost	Net periodic benefit costs as reflected in PG&E Corporation’s Consolidated Statements of Income were as follows: Pension Plan (in millions) 2023 2022 2021 Service cost for benefits earned (1) $ 379 $ 575 $ 587 Interest cost 913 692 645 Expected return on plan assets (981) (1,189) (1,046) Amortization of prior service cost (4) (4) (6) Amortization of net actuarial loss 1 2 6 Net periodic benefit cost 308 76 186 Less: transfer to regulatory account (2) 25 254 147 Total expense recognized $ 333 $ 330 $ 333 (1) A portion of service costs are capitalized pursuant to ASU 2017-07. (2) The Utility recorded these amounts to a regulatory account as they are probable of recovery through future rates. Postretirement Benefits Other than Pensions (in millions) 2023 2022 2021 Service cost for benefits earned (1) $ 38 $ 62 $ 63 Interest cost 73 53 51 Expected return on plan assets (132) (130) (137) Amortization of prior service cost 3 7 14 Amortization of net actuarial gain (19) (40) (33) Special termination benefits — 22 — Net periodic benefit cost $ (37) $ (26) $ (42) (1) A portion of service costs are capitalized pursuant to ASU 2017-07.
Schedule of Assumptions Used in Calculating Projected Benefit Cost and Net Periodic Benefit Cost	The following weighted average year-end actuarial assumptions were used in determining the plans’ projected benefit obligations and net benefit costs. Pension Plan PBOP Plans December 31, December 31, 2023 2022 2021 2023 2022 2021 Discount rate 5.21 % 5.54 % 3.03 % 5.18 - 5.22% 5.50 - 5.54% 2.97 - 3.04% Rate of future compensation increases 3.80 % 3.80 % 3.80 % N/A N/A N/A Expected return on plan assets 6.00 % 6.10 % 5.50 % 3.70 - 7.00% 3.70 - 7.30% 3.30 - 6.40% Interest crediting rate for cash balance plan 3.86 % 4.19 % 1.95 % N/A N/A N/A
Target Asset Allocation Percentages	The target asset allocation percentages for major categories of trust assets for pension and other benefit plans are as follows: Pension Plan PBOP Plans 2024 2023 2022 2024 2023 2022 Global equity securities 26 % 26 % 30 % 29 % 28 % 26 % Absolute return 1 % 1 % 2 % — % 1 % 1 % Real assets 8 % 8 % 8 % 3 % 3 % 3 % Fixed-income securities 65 % 65 % 60 % 68 % 68 % 70 % Total 100 % 100 % 100 % 100 % 100 % 100 %
Schedule of Changes in Fair Value of Plan Assets	The following tables present the fair value of plan assets for pension and other benefits plans by major asset category at December 31, 2023 and 2022. Fair Value Measurements At December 31, 2023 2022 (in millions) Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Pension Plan: Short-term investments $ 565 $ 86 $ — $ 651 $ 461 $ 126 $ — $ 587 Global equity securities 1,270 — — 1,270 1,430 — — 1,430 Real assets 472 — — 472 426 — — 426 Fixed-income securities 1,926 6,802 13 8,741 1,946 6,086 8 8,040 Assets measured at NAV — — — 6,080 — — — 5,886 Total $ 4,233 $ 6,888 $ 13 $ 17,214 $ 4,263 $ 6,212 $ 8 $ 16,369 PBOP Plans: Short-term investments $ 30 $ — $ — $ 30 $ 26 $ — $ — $ 26 Global equity securities 66 — — 66 83 — — 83 Real assets 32 — — 32 29 — — 29 Fixed-income securities 422 795 1 1,218 406 702 1 1,109 Assets measured at NAV — — — 1,160 — — — 1,100 Total $ 550 $ 795 $ 1 $ 2,506 $ 544 $ 702 $ 1 $ 2,347 Total plan assets at fair value $ 19,720 $ 18,716
Schedule of Level 3 Reconciliation	The following table is a reconciliation of changes in the fair value of instruments for the pension plan that have been classified as Level 3 for the years ended December 31, 2023 and 2022: (in millions) For the year ended December 31, 2023 Fixed-Income Balance at beginning of year $ 8 Actual return on plan assets: Relating to assets still held at the reporting date 2 Relating to assets sold during the period (1) Purchases, issuances, sales, and settlements: Purchases 10 Settlements (6) Balance at end of year $ 13 (in millions) For the year ended December 31, 2022 Fixed-Income Balance at beginning of year $ 27 Actual return on plan assets: Relating to assets still held at the reporting date 1 Relating to assets sold during the period — Purchases, issuances, sales, and settlements: Purchases 6 Settlements (26) Balance at end of year $ 8
Schedule of Estimated Benefits Expected to be Paid	As of December 31, 2023, the estimated benefits expected to be paid and the estimated federal subsidies expected to be received in each of the next five fiscal years, and in aggregate for the five fiscal years thereafter, are as follows: (in millions) Pension PBOP Federal 2024 957 93 (4) 2025 1,040 93 (1) 2026 1,066 96 (1) 2027 1,089 87 (1) 2028 1,111 89 (1) Thereafter in the succeeding five years 5,802 471 (4)

RELATED PARTY AGREEMENTS AND _2

RELATED PARTY AGREEMENTS AND TRANSACTIONS (Tables)	12 Months Ended
RELATED PARTY AGREEMENTS AND TRANSACTIONS (Tables)	Dec. 31, 2023
Related Party Transactions [Abstract]
Schedule of Significant Related Party Transactions	The Utility’s significant related party transactions were: Year Ended December 31, (in millions) 2023 2022 2021 Utility revenues from: Administrative services provided to PG&E Corporation $ 3 $ 3 $ 3 Utility expenses from: Administrative services received from PG&E Corporation $ 80 $ 104 $ 82 Utility employee benefit due to PG&E Corporation 74 85 39

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES (Tables)	12 Months Ended
WILDFIRE-RELATED CONTINGENCIES (Tables)	Dec. 31, 2023
Commitments and Contingencies Disclosure [Abstract]
Summary of Wildfire-Related Claims	The following table presents the cumulative charges PG&E Corporation and the Utility have paid through December 31, 2023. Payments (in millions) 2019 Kincade Fire $ 667 2020 Zogg Fire 390 2021 Dixie Fire 731 2022 Mosquito Fire 15 Total at December 31, 2023 $ 1,803 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 100 Payments (292) Balance at December 31, 2023 $ 458 The following table presents changes in the best estimate 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 (22) Balance at December 31, 2023 $ 10 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 425 Payments (686) Balance at December 31, 2023 $ 870 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 2022 Mosquito fire since December 31, 2022. Loss Accrual (in millions) Balance at December 31, 2022 $ 99 Accrued Losses — Payments (14) Balance at December 31, 2023 $ 85 Total probable recoveries for the 2021 Dixie fire and the 2022 Mosquito fire as of December 31, 2023 are: Potential Recovery Source (in millions) 2022 Mosquito fire 2021 Dixie fire Insurance $ 63 $ 526 FERC TO rates 8 91 WEMA 52 470 Wildfire Fund — 600 Probable recoveries at December 31, 2023 (1) $ 123 $ 1,687 (1) Includes legal costs of $23 million and $82 million related to the 2022 Mosquito fire and 2021 Dixie fire, respectively, as of December 31, 2023. The balances for insurance receivables with respect to wildfires are included in Other accounts receivable in PG&E Corporation’s and the Utility’s Consolidated Balance Sheets: Insurance Receivable (in millions) 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) 18 (4) 4 — 18 Reimbursements — (200) (75) (101) (376) Balance at December 31, 2023 $ 63 $ 326 $ 47 $ — $ 436 (1) For the year ended December 31, 2023, the accrued insurance recoveries decreased for the 2021 Dixie fire with a corresponding increase to the 2020 Zogg fire for $4 million.

OTHER CONTINGENCIES AND COMMI_2

OTHER CONTINGENCIES AND COMMITMENTS (Tables)	12 Months Ended
OTHER CONTINGENCIES AND COMMITMENTS (Tables)	Dec. 31, 2023
Commitments and Contingencies Disclosure [Abstract]
Schedule of Environmental Remediation Liability	The Utility’s environmental remediation liability is primarily included in Noncurrent liabilities on the Consolidated Balance Sheets and is comprised of the following: Balance at (in millions) December 31, 2023 December 31, 2022 Topock natural gas compressor station $ 276 $ 284 Hinkley natural gas compressor station 104 110 Former MGP sites owned by the Utility or third parties (1) 809 750 Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites (2) 107 112 Fossil fuel-fired generation facilities and sites (3) 19 26 Total environmental remediation liability $ 1,315 $ 1,282 (1) Primarily driven by the following sites: San Francisco Beach Street, Napa, and San Francisco East Harbor. (2) Primarily driven by geothermal landfill and Shell Pond site. (3) Primarily driven by the San Francisco Potrero Power Plant.
Schedule of Undiscounted Future Expected Power Purchase Agreement Payments	The following table shows the undiscounted future expected obligations under power purchase agreements that have been approved by the CPUC and have met specified construction milestones as well as undiscounted future expected payment obligations for natural gas supplies, natural gas transportation, natural gas storage, and nuclear fuel as of December 31, 2023: Power Purchase Agreements (in millions) Renewable Conventional Natural Other (1) Total 2024 $ 2,005 $ 481 $ 584 $ 301 $ 3,371 2025 1,995 819 171 202 3,187 2026 1,935 766 123 275 3,099 2027 1,883 682 53 132 2,750 2028 1,827 683 — 41 2,552 Thereafter 15,676 1,501 — 9 17,186 Total purchase commitments $ 25,321 $ 4,932 $ 931 $ 960 $ 32,145 (1) Includes other power purchase agreements and nuclear fuel agreements.
Schedule of Other Commitments	At December 31, 2023, the future minimum payments related to these commitments were as follows: (in millions) Other Commitments 2024 $ 55 2025 29 2026 2 2027 — 2028 — Thereafter — Total minimum lease payments $ 86

ORGANIZATION AND BASIS OF PRE_2

ORGANIZATION AND BASIS OF PRESENTATION (Details)	12 Months Ended
ORGANIZATION AND BASIS OF PRESENTATION (Details)	Dec. 31, 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 (10K Narrative) (Details) ft² in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($) ft² facility	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Public Utility, Property, Plant and Equipment [Line Items]
Restricted cash	$ 297	$ 213
Period for probable revenue recovery	24 months
Wildfire Fund Asset
Public Utility, Property, Plant and Equipment [Line Items]
Finite-lived intangible asset, useful life	15 years
Pacific Gas & Electric Co (Utility)
Public Utility, Property, Plant and Equipment [Line Items]
Restricted cash	$ 294	$ 213
Composite depreciation rate	3.56%	3.74%	3.82%
AFUDC debt recorded	$ 82	$ 81	$ 56
AFUDC equity recorded	$ 179	$ 184	$ 133
Pacific Gas & Electric Co (Utility) \| The Lakeside Building
Public Utility, Property, Plant and Equipment [Line Items]
Rentable square feet \| ft²	910
Pacific Gas & Electric Co (Utility) \| Diablo Canyon
Public Utility, Property, Plant and Equipment [Line Items]
Number of generation facilities \| facility	2

SUMMARY OF SIGNIFICANT ACCOUN_5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Revenues Disaggregated by Type of Customer) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Disaggregation of Revenue [Abstract]
Total operating revenues	$ 24,428	$ 21,680	$ 20,642
Electric
Disaggregation of Revenue [Abstract]
Total operating revenues	17,424	15,060	15,131
Natural gas
Disaggregation of Revenue [Abstract]
Total operating revenues	7,004	6,620	5,511
Pacific Gas & Electric Co (Utility)
Disaggregation of Revenue [Abstract]
Total operating revenues	24,428	21,680	20,642
Pacific Gas & Electric Co (Utility) \| Electric
Disaggregation of Revenue [Abstract]
Total operating revenues	15,100	14,832	14,178
Regulatory balancing accounts	2,324	228	953
Total operating revenues	17,424	15,060	15,131
Pacific Gas & Electric Co (Utility) \| Electric \| Residential
Disaggregation of Revenue [Abstract]
Total operating revenues	6,041	6,130	6,089
Pacific Gas & Electric Co (Utility) \| Electric \| Commercial
Disaggregation of Revenue [Abstract]
Total operating revenues	5,643	5,416	5,042
Pacific Gas & Electric Co (Utility) \| Electric \| Industrial
Disaggregation of Revenue [Abstract]
Total operating revenues	1,784	1,626	1,493
Pacific Gas & Electric Co (Utility) \| Electric \| Agricultural
Disaggregation of Revenue [Abstract]
Total operating revenues	1,413	1,830	1,565
Pacific Gas & Electric Co (Utility) \| Electric \| Public street and highway lighting
Disaggregation of Revenue [Abstract]
Total operating revenues	83	77	73
Pacific Gas & Electric Co (Utility) \| Electric \| Other, net
Disaggregation of Revenue [Abstract]
Total operating revenues	136	(247)	(84)
Pacific Gas & Electric Co (Utility) \| Natural gas
Disaggregation of Revenue [Abstract]
Total operating revenues	6,196	6,055	4,958
Regulatory balancing accounts	808	565	553
Total operating revenues	7,004	6,620	5,511
Pacific Gas & Electric Co (Utility) \| Natural gas \| Residential
Disaggregation of Revenue [Abstract]
Total operating revenues	3,686	3,353	2,759
Pacific Gas & Electric Co (Utility) \| Natural gas \| Commercial
Disaggregation of Revenue [Abstract]
Total operating revenues	1,052	1,005	713
Pacific Gas & Electric Co (Utility) \| Natural gas \| Transportation service only
Disaggregation of Revenue [Abstract]
Total operating revenues	1,603	1,534	1,346
Pacific Gas & Electric Co (Utility) \| Natural gas \| Other, net
Disaggregation of Revenue [Abstract]
Total operating revenues	$ (145)	$ 163	$ 140

SUMMARY OF SIGNIFICANT ACCOUN_6

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Allowance for Doubtful Accounts and Credit Losses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Public Utility, Property, Plant and Equipment [Line Items]
Credit losses	$ 636	$ 143	$ 154
Regulatory assets	17,189	16,443
Regulatory Balancing Accounts Receivable
Public Utility, Property, Plant and Equipment [Line Items]
Total regulatory balancing accounts	5,660	3,264
COVID-19 pandemic protection memorandum account, undercollection bad debt
Public Utility, Property, Plant and Equipment [Line Items]
Regulatory assets	5	4
FERC TO rates
Public Utility, Property, Plant and Equipment [Line Items]
Regulatory assets	78
Regulatory assets		8
COVID-19 Pandemic protection memorandum account
Public Utility, Property, Plant and Equipment [Line Items]
Regulatory assets	17	26
Regulatory assets		3
Residential uncollectibles balancing accounts \| Regulatory Balancing Accounts Receivable
Public Utility, Property, Plant and Equipment [Line Items]
Total regulatory balancing accounts	$ 507	$ 126

SUMMARY OF SIGNIFICANT ACCOUN_7

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Schedule of Estimated Useful Lives and Balances of Utilities Property, Plant and Equipment) (Details) - Pacific Gas & Electric Co (Utility) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 115,414	$ 107,153
Accumulated depreciation	(33,093)	(30,946)
Net property, plant, and equipment	82,321	76,207
Electricity generating facilities
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	11,423	11,781
Electricity generating facilities \| Northern California Wildfire
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 1,700
Electricity generating facilities \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	3 years
Electricity generating facilities \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	75 years
Electricity distribution facilities
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 45,205	41,061
Electricity distribution facilities \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	10 years
Electricity distribution facilities \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	70 years
Electricity transmission facilities
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 17,562	16,413
Electricity transmission facilities \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	15 years
Electricity transmission facilities \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	75 years
Natural gas distribution facilities
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 16,324	15,366
Natural gas distribution facilities \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	20 years
Natural gas distribution facilities \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	60 years
Natural gas transmission and storage facilities
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 10,496	9,859
Natural gas transmission and storage facilities \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	5 years
Natural gas transmission and storage facilities \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	70 years
General plant and other
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 9,165	8,518
General plant and other \| Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	5 years
General plant and other \| Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated Useful Lives (years)	50 years
Financing lease
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 787	18
Construction work in progress
Public Utility, Property, Plant and Equipment [Line Items]
Total property, plant, and equipment	$ 4,452	$ 4,137

SUMMARY OF SIGNIFICANT ACCOUN_8

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Schedule of Changes in Asset Retirement Obligations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO liability at beginning of year	$ 5,912	$ 5,298
Liabilities incurred	0	134
Revision in estimated cash flows	(585)	325
Accretion	253	213
Liabilities settled	(68)	(58)
ARO liability at end of year	$ 5,512	$ 5,912

SUMMARY OF SIGNIFICANT ACCOUN_9

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Asset Retirement Obligation (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Public Utility, Property, Plant and Equipment [Line Items]
Asset retirement obligation	$ 5,512	$ 5,512	$ 5,912	$ 5,298
Revision in estimated cash flows		(585)	325
Decrease in decommissioning cost		253
Pacific Gas & Electric Co (Utility)
Public Utility, Property, Plant and Equipment [Line Items]
Asset retirement obligation	5,500	5,500	5,900
Revision in estimated cash flows	$ (205)
Nuclear decommissioning obligation accrued		$ 4,000	$ 4,100

SUMMARY OF SIGNIFICANT ACCOU_10

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Government Assistance (Details) - USD ($)			12 Months Ended
	Jan. 11, 2024	Oct. 18, 2022	Dec. 31, 2023	Dec. 31, 2022
Public Utility, Property, Plant and Equipment [Line Items]
Government Assistance, Statement of Income or Comprehensive Income [Extensible Enumeration]			Total deduction to Operating Expenses
Senate Bill 846 \| Pacific Gas & Electric Co (Utility)
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount		$ 1,100,000,000
Maximum \| Senate Bill 846 \| Pacific Gas & Electric Co (Utility)
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount		1,400,000,000
Performance-Based Disbursement
Public Utility, Property, Plant and Equipment [Line Items]
Disbursement		7
Maximum disbursement		$ 300,000,000
Performance-Based Disbursement \| Cost of Goods and Services Sold, Electricity
Public Utility, Property, Plant and Equipment [Line Items]
Reimbursement amount			$ 56,000,000	$ 0
Civil Nuclear Credit Program \| Subsequent Event
Public Utility, Property, Plant and Equipment [Line Items]
Disbursement	$ 1,100,000,000
Civil Nuclear Credit Program \| Cost of Goods and Services Sold, Electricity
Public Utility, Property, Plant and Equipment [Line Items]
Reimbursement amount			76,000,000
Civil Nuclear Credit Program \| Utilities Operating Expense, Maintenance and Operations
Public Utility, Property, Plant and Equipment [Line Items]
Reimbursement amount			$ 115,000,000

SUMMARY OF SIGNIFICANT ACCOU_11

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - DWR Loan (Details) - DWR Loan - USD ($) $ in Millions		12 Months Ended
	Jan. 11, 2024	Dec. 31, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Beginning balance		$ 312	$ 0
Proceeds received		0	350
Total deduction to Operating Expenses		(214)	(38)
Ending balance		98	312
Subsequent Event
Debt Instrument [Line Items]
Proceeds received	$ 233
Performance-Based Disbursements
Debt Instrument [Line Items]
Total deduction to Operating Expenses		(124)	(38)
Loan Forgiven
Debt Instrument [Line Items]
Total deduction to Operating Expenses		$ (90)	$ 0

SUMMARY OF SIGNIFICANT ACCOU_12

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - VIE (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022	Nov. 30, 2022	Jul. 20, 2022	May 10, 2022	Nov. 12, 2021
Receivables Securitization Program \| PG&E AR Facility, LLC (SPV)
Public Utility, Property, Plant and Equipment [Line Items]
Accounts receivable, net	$ 2,700	$ 3,600
Receivables Securitization Program \| Pacific Gas & Electric Co (Utility)
Public Utility, Property, Plant and Equipment [Line Items]
Long-term debt, gross	1,499	1,200
Recovery Bonds \| Secured Debt
Public Utility, Property, Plant and Equipment [Line Items]
Long-term debt, gross	9,124	9,292
Debt instrument, face amount	1,800	1,800				$ 860
Series 2022-A Recovery Bonds
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount			$ 983
SB 901 Securitization \| Secured Debt
Public Utility, Property, Plant and Equipment [Line Items]
Debt instrument, face amount	$ 7,300	$ 7,500		$ 3,900	$ 3,600

SUMMARY OF SIGNIFICANT ACCOU_13

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Wildfire Fund (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Public Utility, Property, Plant and Equipment [Line Items]
Litigation liability, current	$ 193
Wildfire Fund asset	450	$ 460
Litigation contribution, net	4,300
Amortization and accretion	567	477	$ 517
Insurance receivable	436	794
2021 Dixie fire
Public Utility, Property, Plant and Equipment [Line Items]
Insurance receivable	326	530
Pacific Gas & Electric Co (Utility)
Public Utility, Property, Plant and Equipment [Line Items]
Wildfire Fund asset	450	460
Amortization and accretion	567	$ 477	$ 517
Other Current Liabilities
Public Utility, Property, Plant and Equipment [Line Items]
Wildfire fund, noncurrent	750
Other noncurrent assets – other \| 2021 Dixie fire
Public Utility, Property, Plant and Equipment [Line Items]
Insurance receivable	325
Other noncurrent assets – other \| Pacific Gas & Electric Co (Utility) \| 2021 Dixie fire
Public Utility, Property, Plant and Equipment [Line Items]
Insurance receivable	$ 275

SUMMARY OF SIGNIFICANT ACCOU_14

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Reclassifications Out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	$ 23,075	$ 21,223
Loss on investments	8	(6)
Net current period other comprehensive gain (loss)	(8)	15
Ending balance	25,292	23,075
Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, before reclassification	0	0
Loss on investments	0	0
Net current period other comprehensive gain (loss)	(16)	21
Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, before reclassification	0	0
Loss on investments	0	0
Net current period other comprehensive gain (loss)	0	0
Customer Credit Trust
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, before reclassification	3	3
Loss on investments	8	(6)
Net current period other comprehensive gain (loss)	8	(6)
Accumulated Other Comprehensive Income (Loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	0	(15)
Ending balance	(8)	0
Accumulated Other Comprehensive Income (Loss) \| Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(12)	(33)
Ending balance	(28)	(12)
Accumulated Other Comprehensive Income (Loss) \| Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	18	18
Ending balance	18	18
Accumulated Other Comprehensive Income (Loss) \| Customer Credit Trust
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(6)	0
Ending balance	2	(6)
Amortization of net actuarial gain (loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications:	(123)	8
Amounts reclassified from other comprehensive income	(13)	(28)
Amortization of net actuarial gain (loss) \| Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications, tax	76	102
Other comprehensive income before reclassifications:	(196)	263
Amount attributable to tax, reclassification	0	1
Amounts reclassified from other comprehensive income	1	1
Amortization of net actuarial gain (loss) \| Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications, tax	28	99
Other comprehensive income before reclassifications:	73	(255)
Amount attributable to tax, reclassification	5	11
Amounts reclassified from other comprehensive income	(14)	(29)
Amortization of net actuarial gain (loss) \| Customer Credit Trust
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications, tax	0	0
Other comprehensive income before reclassifications:	0	0
Amount attributable to tax, reclassification	0	0
Amounts reclassified from other comprehensive income	0	0
Regulatory account transfer
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications:	107	13
Amounts reclassified from other comprehensive income	14	26
Regulatory account transfer \| Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications, tax	70	94
Other comprehensive income before reclassifications:	180	(242)
Amount attributable to tax, reclassification	1	0
Amounts reclassified from other comprehensive income	2	2
Regulatory account transfer \| Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications, tax	28	99
Other comprehensive income before reclassifications:	(73)	255
Amount attributable to tax, reclassification	4	9
Amounts reclassified from other comprehensive income	12	24
Regulatory account transfer \| Customer Credit Trust
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Other comprehensive income before reclassifications, tax	0	0
Other comprehensive income before reclassifications:	0	0
Amount attributable to tax, reclassification	0	0
Amounts reclassified from other comprehensive income	0	0
Amortization of prior service cost
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(1)	2
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	1
Amounts reclassified from other comprehensive income	(3)	(3)
Amortization of prior service cost \| Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amount attributable to tax, reclassification	1	2
Amounts reclassified from other comprehensive income	2	5
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
Amounts reclassified from other comprehensive income	$ 0	$ 0

SUMMARY OF SIGNIFICANT ACCOU_15

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Leases (Details) ft² in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($) ft²	Dec. 31, 2022 USD ($)	Jun. 30, 2025 USD ($)	Jul. 11, 2024 USD ($)	Jul. 11, 2023 USD ($)	Oct. 23, 2020 USD ($) ft²
Lessee, Lease, Description [Line Items]
Cash payments for financing lease	$ 142
Financing lease, right of use asset, net	787
Accumulated amortization	108
Leasehold improvements	218
Leasehold incentives	134
Financing lease liabilities	259	$ 0
Financing lease liabilities	$ 554	0
Weighted average remaining lease term, finance lease	1 year 7 months 6 days
Weighted average discount rate, finance lease	6.50%
Lease payments	$ 1,900	$ 2,300
Weighted average remaining lease term. operating lease	8 years 2 months 12 days	19 years 7 months 6 days
Weighted average discount rate, operating lease	6.40%	6.50%
Pacific Gas & Electric Co (Utility)
Lessee, Lease, Description [Line Items]
Financing lease liabilities	$ 259	$ 0
Financing lease liabilities	$ 554	$ 0
Oakland Headquarters Lease \| Pacific Gas & Electric Co (Utility)
Lessee, Lease, Description [Line Items]
Rentable square feet \| ft²	659					910
Lease, option payment letter of credit						$ 75
Lease, security letter of credit						$ 75
Purchase price					$ 906
Purchase price, deposits					$ 150
Oakland Headquarters Lease \| Pacific Gas & Electric Co (Utility) \| Forecast
Lessee, Lease, Description [Line Items]
Purchase price, deposits			$ 506	$ 250
Purchase price, deposits credit			$ 172

SUMMARY OF SIGNIFICANT ACCOU_16

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Schedule of Lease Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Financing lease fixed cost:
Amortization of ROU assets	$ 115
Interest on lease liabilities	27
Financing lease variable cost	3
Total financing lease costs	145
Operating Lease Costs [Abstract]
Operating lease fixed cost	269	$ 500
Operating lease variable cost	1,632	1,829
Total operating lease costs	$ 1,901	$ 2,329

SUMMARY OF SIGNIFICANT ACCOU_17

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Future Expected Operating Lease Payments) (Details) $ in Millions	Dec. 31, 2023 USD ($)
Future Expected Finance Lease Payments
2024	$ 305
2025	531
2026	44
2027	0
2028	0
Total lease payments	880
Less imputed interest	(67)
Total	813
Future Expected Operating Lease Payments
2024	116
2025	115
2026	112
2027	110
2028	97
Thereafter	256
Total lease payments	806
Less imputed interest	(208)
Total	$ 598

REGULATORY ASSETS, LIABILITIE_3

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Jun. 30, 2022	Feb. 28, 2022
Regulatory Assets [Line Items]
Regulatory assets	$ 17,189	$ 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]
Regulatory assets	17,189	16,443
Pension benefits
Regulatory Assets [Line Items]
Regulatory assets	348	120
Environmental compliance costs
Regulatory Assets [Line Items]
Regulatory assets	$ 1,218	1,193
Recovery Period	32 years
Utility retained generation
Regulatory Assets [Line Items]
Regulatory assets	$ 39	86
Recovery Period	4 years
Price risk management
Regulatory Assets [Line Items]
Regulatory assets	$ 160	177
Recovery Period	16 years 6 months
Catastrophic event memorandum account
Regulatory Assets [Line Items]
Regulatory assets	$ 1,074	1,085
Catastrophic event memorandum account \| COVID-19
Regulatory Assets [Line Items]
Regulatory assets	$ 43	44
Catastrophic event memorandum account \| Minimum
Regulatory Assets [Line Items]
Recovery Period	1 year
Catastrophic event memorandum account \| Maximum
Regulatory Assets [Line Items]
Recovery Period	3 years
Wildfire expense memorandum account
Regulatory Assets [Line Items]
Regulatory assets	$ 540	439
Fire hazard prevention memorandum account
Regulatory Assets [Line Items]
Regulatory assets	$ 7	79
Fire hazard prevention memorandum account \| Minimum
Regulatory Assets [Line Items]
Recovery Period	1 year
Fire hazard prevention memorandum account \| Maximum
Regulatory Assets [Line Items]
Recovery Period	2 years
Fire risk mitigation memorandum account
Regulatory Assets [Line Items]
Regulatory assets	$ 110	65
Fire risk mitigation memorandum account \| Minimum
Regulatory Assets [Line Items]
Recovery Period	1 year
Fire risk mitigation memorandum account \| Maximum
Regulatory Assets [Line Items]
Recovery Period	3 years
Wildfire mitigation plan memorandum account
Regulatory Assets [Line Items]
Regulatory assets	$ 541	756
Wildfire mitigation plan memorandum account \| Minimum
Regulatory Assets [Line Items]
Recovery Period	1 year
Wildfire mitigation plan memorandum account \| Maximum
Regulatory Assets [Line Items]
Recovery Period	3 years
Deferred income taxes
Regulatory Assets [Line Items]
Regulatory assets	$ 3,543	2,730
Recovery Period	51 years
Insurance premium costs
Regulatory Assets [Line Items]
Regulatory assets	$ 1	99
Insurance premium costs \| Minimum
Regulatory Assets [Line Items]
Recovery Period	2 years
Insurance premium costs \| Maximum
Regulatory Assets [Line Items]
Recovery Period	4 years
Wildfire mitigation balancing account
Regulatory Assets [Line Items]
Regulatory assets	$ 120	327
Wildfire mitigation balancing account \| Minimum
Regulatory Assets [Line Items]
Recovery Period	1 year
Cost percentage threshold requiring approval	115%
Wildfire mitigation balancing account \| Maximum
Regulatory Assets [Line Items]
Recovery Period	4 years
Vegetation management balancing account
Regulatory Assets [Line Items]
Regulatory assets	$ 1,538	2,276
Cost percentage threshold requiring approval	120%
Vegetation management balancing account \| Minimum
Regulatory Assets [Line Items]
Recovery Period	1 year
Vegetation management balancing account \| Maximum
Regulatory Assets [Line Items]
Recovery Period	3 years
COVID-19 Pandemic protection memorandum account
Regulatory Assets [Line Items]
Regulatory assets	$ 17	26
COVID-19 Pandemic protection memorandum account \| Minimum
Regulatory Assets [Line Items]
Recovery Period	1 year
COVID-19 Pandemic protection memorandum account \| Maximum
Regulatory Assets [Line Items]
Recovery Period	3 years
COVID-19 pandemic protection memorandum account, undercollection bad debt
Regulatory Assets [Line Items]
Regulatory assets	$ 5	4
COVID-19 pandemic protection memorandum account, program and accounts receivable financing costs
Regulatory Assets [Line Items]
Regulatory assets	12	22
Microgrid memorandum account
Regulatory Assets [Line Items]
Regulatory assets	$ 59	213
Microgrid memorandum account \| Minimum
Regulatory Assets [Line Items]
Recovery Period	1 year
Microgrid memorandum account \| Maximum
Regulatory Assets [Line Items]
Recovery Period	3 years
Financing costs
Regulatory Assets [Line Items]
Regulatory assets	$ 196	211
SB 901 Securitization
Regulatory Assets [Line Items]
Regulatory assets	$ 5,249	5,378	$ 5,500
Recovery Period	30 years
Recoveries in excess of AROs
Regulatory Assets [Line Items]
Regulatory assets	$ 73	120
General rate case memorandum accounts
Regulatory Assets [Line Items]
Regulatory assets	$ 1,291	0
General rate case memorandum accounts \| Minimum
Regulatory Assets [Line Items]
Recovery Period	1 year
General rate case memorandum accounts \| Maximum
Regulatory Assets [Line Items]
Recovery Period	2 years
Other
Regulatory Assets [Line Items]
Regulatory assets	$ 1,065	$ 1,063

REGULATORY ASSETS, LIABILITIE_4

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Liabilities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Jun. 30, 2022
Regulatory Liabilities [Line Items]
Total noncurrent regulatory liabilities	$ 19,444	$ 17,630
Proceeds received from sale of transmission tower wireless licenses, to be refunded to customers	384
Authorized amount of shareholder tax benefits to be returned	7,590
Pacific Gas & Electric Co (Utility)
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1,200	1,100
Total noncurrent regulatory liabilities	19,444	17,630
Federal Energy Regulatory Commission
Regulatory Liabilities [Line Items]
Proceeds received from sale of transmission tower wireless licenses, to be refunded to customers	288
California Public Utilities Commission
Regulatory Liabilities [Line Items]
Proceeds received from sale of transmission tower wireless licenses, to be refunded to customers	96
Cost of removal obligations
Regulatory Liabilities [Line Items]
Total noncurrent regulatory liabilities	8,191	7,773
Public purpose programs
Regulatory Liabilities [Line Items]
Total noncurrent regulatory liabilities	1,238	1,062
Employee benefit plans
Regulatory Liabilities [Line Items]
Total noncurrent regulatory liabilities	1,032	904
Transmission tower wireless licenses
Regulatory Liabilities [Line Items]
Total noncurrent regulatory liabilities	384	430
SFGO sale
Regulatory Liabilities [Line Items]
Total noncurrent regulatory liabilities	185	264
SB 901 Securitization
Regulatory Liabilities [Line Items]
Total noncurrent regulatory liabilities	6,628	5,800	$ 5,540
Wildfire self-insurance
Regulatory Liabilities [Line Items]
Total noncurrent regulatory liabilities	407	0
Other
Regulatory Liabilities [Line Items]
Total noncurrent regulatory liabilities	$ 1,379	$ 1,397

REGULATORY ASSETS, LIABILITIE_5

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Current Regulatory Balancing Accounts, Net) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Regulatory Assets [Line Items]
Interest income	$ 606	$ 162	$ 20
Regulatory assets	300	296
Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	1,669	1,658
Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Interest income	547	153	$ 18
Total regulatory balancing accounts	5,660	3,264
Electric distribution \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	1,092	448
Electric transmission \| Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	200	228
Electric transmission \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	99	96
Gas distribution and transmission \| Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	224	66
Gas distribution and transmission \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	144	72
Energy procurement \| Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	77	428
Energy procurement \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	1,002	684
Public purpose programs \| Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	299	272
Public purpose programs \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	137	358
Fire hazard prevention memorandum account \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	40	0
Wildfire mitigation plan memorandum account \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	161	0
Wildfire mitigation balancing account \| Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	125	0
Wildfire mitigation balancing account \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	12	2
Nuclear decommissioning adjustment mechanism \| Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	216	8
Vegetation management balancing account \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	340	137
Insurance premium costs
Regulatory Assets [Line Items]
Regulatory assets	0	48
Insurance premium costs \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	227	602
Residential uncollectibles balancing accounts \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	507	126
Catastrophic event memorandum account \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	413	144
General rate case memorandum accounts \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	1,097	0
SFGO sale \| Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	79	152
Other \| Regulatory Balancing Accounts Payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	449	504
Other \| Regulatory Balancing Accounts Receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts	$ 389	$ 595

DEBT (Outstanding Borrowings an

DEBT (Outstanding Borrowings and Availability) (Details) - USD ($)	Dec. 31, 2023	Jun. 09, 2023	Jun. 08, 2023	Dec. 31, 2022
Revolving Credit Facility
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	$ 6,399,000,000
Loans Outstanding	(3,249,000,000)
Letters of Credit Outstanding	(652,000,000)
Facility Availability	2,498,000,000
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	(1,750,000,000)
Letters of Credit Outstanding	(652,000,000)
Facility Availability	1,998,000,000
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	1,499,000,000
Loans Outstanding	(1,499,000,000)			$ (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)

12 Months Ended

Dec. 08, 2023 USD ($)

Dec. 07, 2023

Dec. 04, 2023 USD ($) day $ / shares

Nov. 15, 2023 USD ($)

Jun. 22, 2023 USD ($) numberOfExtensionOption

Apr. 18, 2023 USD ($)

Dec. 31, 2023 USD ($)

Dec. 31, 2022 USD ($)

Dec. 31, 2021 USD ($)

Nov. 08, 2023 USD ($)

Jun. 09, 2023 USD ($)

Jun. 08, 2023 USD ($)

Jun. 05, 2023 USD ($)

Mar. 30, 2023 USD ($)

Jan. 06, 2023 USD ($)

Debt [Line Items]

Repayments of long-term debt

$ 3,075,000,000

$ 5,968,000,000

$ 87,000,000

Debt financial instrument

50,975,000,000

47,742,000,000

PG&E Corporation

Debt [Line Items]

Repayments of long-term debt

28,000,000

Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Repayments of long-term debt

3,075,000,000

5,941,000,000

$ 59,000,000

Pacific Gas & Electric Co (Utility) | Letter of Credit Subfacility

Debt [Line Items]

Long-term debt, gross

$ 2,000,000,000

Pacific Gas & Electric Co (Utility) | Uncommitted Incremental Facility

Debt [Line Items]

Long-term debt, gross

$ 1,000,000,000

364-Day 2023 Tranche Loans | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Long-term debt, gross

$ 125,000,000

364-Day 2023 Tranche Loans | Pacific Gas & Electric Co (Utility) | SOFR

Debt [Line Items]

Credit spread adjustment

0.10%

Basis spread on variable rate

1.375%

364-Day 2023 Tranche Loans | Pacific Gas & Electric Co (Utility) | Base Rate

Debt [Line Items]

Basis spread on variable rate

0.375%

Revolving Credit Facility

Debt [Line Items]

Long-term debt, gross

3,249,000,000

Line of credit facility, maximum borrowing capacity

6,399,000,000

Revolving Credit Facility | PG&E Corporation

Debt [Line Items]

Long-term debt, gross

Line of credit facility, maximum borrowing capacity

500,000,000

Number of extensions | numberOfExtensionOption

Extension option, term

1 year

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

Debt [Line Items]

Long-term debt, gross

1,750,000,000

Line of credit facility, maximum borrowing capacity

4,400,000,000

Number of extensions | numberOfExtensionOption

Extension option, term

1 year

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

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

Debt [Line Items]

Long-term debt, gross

$ 2,100,000,000

Bridge Term Loan Credit Agreement | Pacific Gas & Electric Co (Utility) | SOFR

Debt [Line Items]

Credit spread adjustment

0.10%

Basis spread on variable rate

1.25%

Bridge Term Loan Credit Agreement | Pacific Gas & Electric Co (Utility) | Base Rate

Debt [Line Items]

Basis spread on variable rate

0.25%

Term Loan | PG&E Corporation

Debt [Line Items]

Basis spread on variable rate

2.50%

Repayments of long-term debt

$ 11,000,000

$ 2,150,000,000

Unamortized discount and issuance costs

26,000,000

Debt financial instrument

$ 500,000,000

Term Loan | SOFR | PG&E Corporation

Debt [Line Items]

Basis spread on variable rate

2.50%

First Mortgage Bonds Due 2033 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Long-term debt, gross

$ 1,900,000,000

Debt instrument, face amount

$ 1,150,000,000

$ 750,000,000

Interest rate

6.40%

6.15%

First Mortgage Bonds Due 2033 | Pacific Gas & Electric Co (Utility) | Minimum

Debt [Line Items]

Interest rate

6.15%

First Mortgage Bonds Due 2033 | Pacific Gas & Electric Co (Utility) | Maximum

Debt [Line Items]

Interest rate

6.40%

First Mortgage Bonds Due 2053 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Debt instrument, face amount

$ 500,000,000

$ 750,000,000

Interest rate

6.75%

6.70%

675%

First Mortgage Bonds, Stated Maturity 2029 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Long-term debt, gross

$ 1,250,000,000

400,000,000

Debt instrument, face amount

$ 850,000,000

Interest rate

6.10%

First Mortgage Bonds, Stated Maturity 2029 | Pacific Gas & Electric Co (Utility) | Minimum

Debt [Line Items]

Interest rate

4.20%

First Mortgage Bonds, Stated Maturity 2029 | Pacific Gas & Electric Co (Utility) | Maximum

Debt [Line Items]

Interest rate

6.10%

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

Debt [Line Items]

Long-term debt, gross

$ 0

2,075,000,000

Debt instrument, face amount

$ 375,000,000

Interest rate

3.25%

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

Debt [Line Items]

Interest rate

1.70%

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

Debt [Line Items]

Interest rate

4.25%

First Mortgage Bonds Due August 2023 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Debt instrument, face amount

$ 500,000,000

Interest rate

4.25%

First Mortgage Bonds Due 2034 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Long-term debt, gross

$ 800,000,000

Debt instrument, face amount

$ 800,000,000

Interest rate

6.95%

First Mortgage Bonds Due November 2023 | Pacific Gas & Electric Co (Utility)

Debt [Line Items]

Debt instrument, face amount

$ 900,000,000

Interest rate

1.70%

Convertible Notes Due 2027 | PG&E Corporation

Debt [Line Items]

Long-term debt, gross

$ 2,150,000,000

$ 0

Interest rate

4.25%

Convertible Notes Due 2027 | PG&E Corporation | Secured Debt

Debt [Line Items]

Debt financial instrument

2,120,000,000

$ 2,120,000,000

Debt instrument, face amount

$ 2,150,000,000

Interest rate

4.25%

Conversion rate

0.0431416

Conversion price | $ / shares

$ 23.18

Debt instrument, redemption price, percentage

100%

Debt issuance costs

27,000,000

Interest expense

$ 7,000,000

Convertible Notes Due 2027 | PG&E Corporation | Secured Debt | Debt Conversion Terms One

Debt [Line Items]

Threshold trading days | day

Threshold consecutive trading days | day

Threshold percentage of stock price

130%

Convertible Notes Due 2027 | PG&E Corporation | Secured Debt | Debt Conversion Terms Two

Debt [Line Items]

Threshold trading days | day

Threshold consecutive trading days | day

Threshold percentage of stock price

90%

DEBT (Schedule of Long-term Deb

DEBT (Schedule of Long-term Debt) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 04, 2023	Nov. 08, 2023	Jun. 05, 2023	Jan. 06, 2023	Dec. 31, 2022	Nov. 12, 2021
Debt [Line Items]
Less: current portion, net of unamortized discount and debt issuance costs	$ (1,376)					$ (2,268)
Long-term debt, net	50,975					47,742
Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Less: current portion, net of unamortized discount and debt issuance costs	(1,376)					(2,241)
PG&E Corporation
Debt [Line Items]
Less: current portion, net of unamortized discount and debt issuance costs	0					(27)
New Debt \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Less: current portion, net of unamortized discount and debt issuance costs	(400)					0
Long-term debt, net	46,376					43,155
New Debt \| PG&E Corporation
Debt [Line Items]
Less: current portion, net of unamortized discount and debt issuance costs	0					(28)
Unamortized discount and debt issuance costs, net	(51)					(66)
Long-term debt, net	4,599					4,587
Term Loan B, Stated Maturity 2027 \| PG&E Corporation
Debt [Line Items]
Long-term debt, gross	$ 500					$ 2,681
Term Loan B, Stated Maturity 2027 \| PG&E Corporation \| LIBOR
Debt [Line Items]
Stated interest rate	7.85%
Term Loan B, Stated Maturity 2027 \| PG&E Corporation \| SOFR
Debt [Line Items]
Stated interest rate						7.44%
Convertible Notes Due 2027 \| PG&E Corporation
Debt [Line Items]
Stated interest rate	4.25%
Long-term debt, gross	$ 2,150					$ 0
Convertible Notes Due 2027 \| PG&E Corporation \| Secured Debt
Debt [Line Items]
Stated interest rate		4.25%
Recovery Bonds		$ 2,150
Long-term debt, net	$ 2,120	$ 2,120
Senior Notes Due 2028 \| PG&E Corporation
Debt [Line Items]
Stated interest rate	5%
Long-term debt, gross	$ 1,000					1,000
Senior Notes Due 2030 \| PG&E Corporation
Debt [Line Items]
Stated interest rate	5.25%
Long-term debt, gross	$ 1,000					1,000
First Mortgage Bonds \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Less: current portion, net of unamortized discount and debt issuance costs	(800)					(2,072)
Unamortized discount and debt issuance costs, net	(246)					(195)
Long-term debt, net	35,831					32,135
First Mortgage Bonds, Stated Maturity 2023 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate				3.25%
Long-term debt, gross	$ 0					2,075
Recovery Bonds				$ 375
First Mortgage Bonds, Stated Maturity 2023 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	1.70%
First Mortgage Bonds, Stated Maturity 2023 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.25%
First Mortgage Bonds, Stated Maturity 2024 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 800					1,800
First Mortgage Bonds, Stated Maturity 2024 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	3.40%
First Mortgage Bonds, Stated Maturity 2024 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	3.75%
First Mortgage Bonds, Stated Maturity 2025 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 1,925					1,925
First Mortgage Bonds, Stated Maturity 2025 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	3.45%
First Mortgage Bonds, Stated Maturity 2025 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.95%
First Mortgage Bonds, Stated Maturity 2026 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 2,551					2,551
First Mortgage Bonds, Stated Maturity 2026 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	2.95%
First Mortgage Bonds, Stated Maturity 2026 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	3.15%
First Mortgage Bonds, Stated Maturity 2027 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 3,000					3,000
First Mortgage Bonds, Stated Maturity 2027 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	2.10%
First Mortgage Bonds, Stated Maturity 2027 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	5.45%
First Mortgage Bonds, Stated Maturity 2028 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 1,975					1,975
First Mortgage Bonds, Stated Maturity 2028 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	3%
First Mortgage Bonds, Stated Maturity 2028 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.65%
First Mortgage Bonds, Stated Maturity 2029 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate				6.10%
Long-term debt, gross	$ 1,250					400
Recovery Bonds				$ 850
First Mortgage Bonds, Stated Maturity 2029 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	4.20%
First Mortgage Bonds, Stated Maturity 2029 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	6.10%
First Mortgage Bonds, Stated Maturity 2030 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate	4.55%
Long-term debt, gross	$ 3,100					3,100
First Mortgage Bonds, Stated Maturity 2031 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 3,000					3,000
First Mortgage Bonds, Stated Maturity 2031 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	2.50%
First Mortgage Bonds, Stated Maturity 2031 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	3.25%
First Mortgage Bonds, Stated Maturity 2032 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 1,050					1,050
First Mortgage Bonds, Stated Maturity 2032 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	4.40%
First Mortgage Bonds, Stated Maturity 2032 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	5.90%
First Mortgage Bonds Due 2033 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate				6.40%	6.15%
Long-term debt, gross	$ 1,900					0
Recovery Bonds				$ 1,150	$ 750
First Mortgage Bonds Due 2033 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	6.15%
First Mortgage Bonds Due 2033 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	6.40%
First Mortgage Bonds Due 2034 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate	6.95%		6.95%
Long-term debt, gross	$ 800					0
Recovery Bonds			$ 800
First Mortgage Bonds, Stated Maturity 2040 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 2,951					2,951
First Mortgage Bonds, Stated Maturity 2040 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	3.30%
First Mortgage Bonds, Stated Maturity 2040 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.50%
First Mortgage Bonds, Stated Maturity 2041 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 700					700
First Mortgage Bonds, Stated Maturity 2041 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	4.20%
First Mortgage Bonds, Stated Maturity 2041 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.50%
First Mortgage Bonds, Stated Maturity 2042 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 750					750
First Mortgage Bonds, Stated Maturity 2042 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	3.75%
First Mortgage Bonds, Stated Maturity 2042 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.45%
First Mortgage Bonds, Stated Maturity 2043 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate	4.60%
Long-term debt, gross	$ 375					375
First Mortgage Bonds, Stated Maturity 2044 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate	4.75%
Long-term debt, gross	$ 675					675
First Mortgage Bonds, Stated Maturity 2045 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 600					600
First Mortgage Bonds, Stated Maturity 2045 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.30%
First Mortgage Bonds, Stated Maturity 2046 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 1,050					1,050
First Mortgage Bonds, Stated Maturity 2046 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	4%
First Mortgage Bonds, Stated Maturity 2046 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.25%
First Mortgage Bonds, Stated Maturity 2047 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 850					850
First Mortgage Bonds, Stated Maturity 2047 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	3.95%
First Mortgage Bonds, Stated Maturity 2050 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 5,025					5,025
First Mortgage Bonds, Stated Maturity 2050 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	3.50%
First Mortgage Bonds, Stated Maturity 2050 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	4.95%
First Mortgage Bonds, Stated Maturity 2052 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Stated interest rate	5.25%
Long-term debt, gross	$ 550					550
First Mortgage Bonds, Stated Maturity 2053 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	$ 2,000					0
First Mortgage Bonds, Stated Maturity 2053 \| Pacific Gas & Electric Co (Utility) \| Minimum
Debt [Line Items]
Stated interest rate	6.70%
First Mortgage Bonds, Stated Maturity 2053 \| Pacific Gas & Electric Co (Utility) \| Maximum
Debt [Line Items]
Stated interest rate	6.75%
Recovery Bonds \| Secured Debt
Debt [Line Items]
Long-term debt, gross	$ 9,124					9,292
Less: current portion, net of unamortized discount and debt issuance costs	(176)					(168)
Recovery Bonds	1,800					1,800	$ 860
DWR Loan
Debt [Line Items]
Long-term debt, net	98					312
Receivables Securitization Program \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Long-term debt, gross	1,499					1,200
Long-term debt, net	$ 1,499					$ 1,184
Receivables Securitization Program \| Pacific Gas & Electric Co (Utility) \| SOFR
Debt [Line Items]
Stated interest rate	6.75%					5.10%
2 Year Term Loan \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Term Loan	$ 400					$ 400
2 Year Term Loan \| Pacific Gas & Electric Co (Utility) \| SOFR
Debt [Line Items]
Stated interest rate	6.60%					5.71%

DEBT (Schedule of Contractual R

DEBT (Schedule of Contractual Repayment Schedule) (Details) $ in Millions	Dec. 31, 2023 USD ($)
Debt [Line Items]
Total consolidated debt	$ 52,551
AB 1054 obligations
Debt [Line Items]
Fixed rate obligations	1,787
SB 901 obligations
Debt [Line Items]
Fixed rate obligations	$ 7,338
Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	4.31%
Fixed rate obligations	$ 36,877
Variable interest rate as of December 31, 2023	6.72%
Variable rate obligations	$ 1,899
PG&E Corporation
Debt [Line Items]
Average fixed interest rate	4.67%
Fixed rate obligations	$ 4,150
Variable interest rate as of December 31, 2023	7.85%
Variable rate obligations	$ 500
2024
Debt [Line Items]
Total consolidated debt	1,376
2024 \| AB 1054 obligations
Debt [Line Items]
Fixed rate obligations	46
2024 \| SB 901 obligations
Debt [Line Items]
Fixed rate obligations	$ 130
2024 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	3.60%
Fixed rate obligations	$ 800
Variable interest rate as of December 31, 2023	6.60%
Variable rate obligations	$ 400
2024 \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	0%
Fixed rate obligations	$ 0
Variable interest rate as of December 31, 2023	0%
Variable rate obligations	$ 0
2025
Debt [Line Items]
Total consolidated debt	3,607
2025 \| AB 1054 obligations
Debt [Line Items]
Fixed rate obligations	48
2025 \| SB 901 obligations
Debt [Line Items]
Fixed rate obligations	$ 135
2025 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	3.82%
Fixed rate obligations	$ 1,925
Variable interest rate as of December 31, 2023	6.75%
Variable rate obligations	$ 1,499
2025 \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	0%
Fixed rate obligations	$ 0
Variable interest rate as of December 31, 2023	0%
Variable rate obligations	$ 0
2026
Debt [Line Items]
Total consolidated debt	2,742
2026 \| AB 1054 obligations
Debt [Line Items]
Fixed rate obligations	50
2026 \| SB 901 obligations
Debt [Line Items]
Fixed rate obligations	$ 141
2026 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	3.10%
Fixed rate obligations	$ 2,551
Variable interest rate as of December 31, 2023	0%
Variable rate obligations	$ 0
2026 \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	0%
Fixed rate obligations	$ 0
Variable interest rate as of December 31, 2023	0%
Variable rate obligations	$ 0
2027
Debt [Line Items]
Total consolidated debt	5,847
2027 \| AB 1054 obligations
Debt [Line Items]
Fixed rate obligations	51
2027 \| SB 901 obligations
Debt [Line Items]
Fixed rate obligations	$ 146
2027 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	3.22%
Fixed rate obligations	$ 3,000
Variable interest rate as of December 31, 2023	0%
Variable rate obligations	$ 0
2027 \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	4.25%
Fixed rate obligations	$ 2,150
Variable interest rate as of December 31, 2023	7.85%
Variable rate obligations	$ 500
2028
Debt [Line Items]
Total consolidated debt	3,180
2028 \| AB 1054 obligations
Debt [Line Items]
Fixed rate obligations	53
2028 \| SB 901 obligations
Debt [Line Items]
Fixed rate obligations	$ 152
2028 \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	3.58%
Fixed rate obligations	$ 1,975
Variable interest rate as of December 31, 2023	0%
Variable rate obligations	$ 0
2028 \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	5%
Fixed rate obligations	$ 1,000
Variable interest rate as of December 31, 2023	0%
Variable rate obligations	$ 0
Thereafter
Debt [Line Items]
Total consolidated debt	35,799
Thereafter \| AB 1054 obligations
Debt [Line Items]
Fixed rate obligations	1,539
Thereafter \| SB 901 obligations
Debt [Line Items]
Fixed rate obligations	$ 6,634
Thereafter \| Pacific Gas & Electric Co (Utility)
Debt [Line Items]
Average fixed interest rate	4.66%
Fixed rate obligations	$ 26,626
Variable interest rate as of December 31, 2023	0%
Variable rate obligations	$ 0
Thereafter \| PG&E Corporation
Debt [Line Items]
Average fixed interest rate	5.25%
Fixed rate obligations	$ 1,000
Variable interest rate as of December 31, 2023	0%
Variable rate obligations	$ 0

SB 901 SECURITIZATION AND CUS_3

SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Debt [Line Items]
Regulatory assets			$ 17,189	$ 16,443
Initial shareholder contribution			2,000
Regulatory liabilities			19,444	17,630
SB 901 securitization charges, net			1,267	608	$ 0
SB 901 Securitization
Debt [Line Items]
Regulatory liabilities	$ 5,540		6,628	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			1,300	608
Amortization of regulatory asset and liability			322
SB 901 Securitization \| Secured Debt \| Forecast
Debt [Line Items]
Initial shareholder contribution		$ 1,000
Nothern California Wild Fire
Debt [Line Items]
Loss contingency, costs incurred	7,500
SB 901 Securitization
Debt [Line Items]
Regulatory assets	$ 5,500		$ 5,249	$ 5,378

SB 901 SECURITIZATION AND CUS_4

SB 901 SECURITIZATION AND CUSTOMER CREDIT TRUST (Financial Statement Impact) (Details) - USD ($) $ in Millions	12 Months Ended	61 Months Ended
	Dec. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Debt [Line Items]
Regulatory assets	$ 17,189		$ 16,443
Ending balance	17,189
Beginning balance	(17,630)
Ending balance	(19,444)
SB 901 Securitization Inception
Debt [Line Items]
Beginning balance	(5,800)
Amortization	451
Additions	(1,279)
Ending balance	(6,628)
SB 901 Securitization Inception \| Customer credit trust
Debt [Line Items]
Additions		$ (12)
SB 901 Securitization Inception
Debt [Line Items]
Regulatory assets	5,249		$ 5,378
Amortization	(129)
Ending balance	$ 5,249

COMMON STOCK AND SHARE-BASED _3

COMMON STOCK AND SHARE-BASED COMPENSATION (Narrative) (Details) - USD ($)				3 Months Ended	12 Months Ended				30 Months Ended	45 Months Ended
	Feb. 14, 2024	Jan. 16, 2024	Nov. 27, 2023	Mar. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021		Dec. 31, 2023	Sep. 30, 2023	Jul. 08, 2021
Schedule of Capitalization, Equity [Line Items]
Common stock, shares outstanding (in shares)					2,133,597,758	1,987,784,948			2,133,597,758
Common stock issued, net					$ (2,517,000,000)	$ (2,337,000,000)	$ 4,854,000,000	[1]
Entity Common Stock, Shares Outstanding (in shares)	2,611,366,666
Common stock dividend declared (in dollars per share)			$ 0.01
Common stock dividends declared					$ 21,000,000
Equity capital structure percentage					52%				52%
Shares available for LTIP award (in shares)					61,716,764				61,716,764
Granted (in dollars per share)					$ 15.70	$ 11.40	$ 11.01
Total fair value					$ 64,000,000	$ 46,000,000	$ 19,000,000
Total unrecognized compensation costs					$ 74,000,000
Remaining weighted average period					1 year 5 months 1 day
Employee Stock Option
Schedule of Capitalization, Equity [Line Items]
Granted (in shares)					0	0
Weighted-average period					1 year 3 months 7 days
Restricted stock units
Schedule of Capitalization, Equity [Line Items]
Award vesting period					3 years
Tax detriment					$ 26,000,000
Performance shares
Schedule of Capitalization, Equity [Line Items]
Award vesting period					3 years
Industry performance period					3 years
Award grant date fair value recognition period					3 years
Performance shares granted (in dollars per share)					$ 13.39	$ 13.44	$ 11.83
Employee service share based compensation nonvested performance shares total compensation cost not yet recognized					$ 43,000,000
2014 LTIP, Amended
Schedule of Capitalization, Equity [Line Items]
Number of shares issued for LTIP, maximum (in shares)					91,000,000				91,000,000
2014 LTIP \| Employee Stock Option
Schedule of Capitalization, Equity [Line Items]
Term of award					10 years
Award vesting period					3 years
Total unrecognized compensation costs					$ 0				$ 0
Granted (in shares)					0
Fire Victim Trust
Schedule of Capitalization, Equity [Line Items]
Number of shares exchanged (in shares)					247,743,590
Shares sold, tax impact					$ 1,200,000,000				$ 2,000,000,000
Number of shares sold (in shares)									477,743,590
Subsequent Event
Schedule of Capitalization, Equity [Line Items]
Common stock dividend declared (in dollars per share)	$ 0.01
Common stock dividends declared		$ 21,000,000
PG&E Corporation
Schedule of Capitalization, Equity [Line Items]
Common stock to be received, value					$ 1,300,000,000				$ 1,300,000,000
PG&E Corporation \| Subsequent Event
Schedule of Capitalization, Equity [Line Items]
Common stock, shares outstanding, adjusted (in shares)	2,133,623,076
PG&E Corporation \| Common Stock
Schedule of Capitalization, Equity [Line Items]
Stock issued during period, shares, new issues (in shares)										137,000,000
Common stock issued, net										$ 1,300,000,000
PG&E Corporation \| Equity Units
Schedule of Capitalization, Equity [Line Items]
Stock issued during period, shares, new issues (in shares)				16,000,000
PG&E Corporation \| Minimum
Schedule of Capitalization, Equity [Line Items]
Percentage of equity security ownership with board of director approval					4.75%				4.75%		4.75%
PG&E Corporation \| Minimum \| Subsequent Event
Schedule of Capitalization, Equity [Line Items]
Percentage of equity security ownership with board of director approval	3.88%
PG&E Corporation \| Minimum \| Common Stock
Schedule of Capitalization, Equity [Line Items]
Amount of shares, right to receive				137,000,000
PG&E Corporation \| Maximum \| Common Stock
Schedule of Capitalization, Equity [Line Items]
Amount of shares, right to receive				168,000,000
Pacific Gas & Electric Co (Utility)
Schedule of Capitalization, Equity [Line Items]
Common stock, shares outstanding (in shares)					477,743,590				477,743,590
Pacific Gas & Electric Co (Utility) \| Fire Victim Trust
Schedule of Capitalization, Equity [Line Items]
Common stock, shares outstanding (in shares)					247,743,590				247,743,590

[1]Excludes 477,743,590 shares of common stock owned by the Utility. For more information, see Note 6 of the Notes to the Consolidated Financial Statements in Item 8 of the 2021 Form 10-K .

COMMON STOCK AND SHARE-BASED _4

COMMON STOCK AND SHARE-BASED COMPENSATION (Long-term Incentive Plan) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense (pre-tax)	$ 91	$ 115	$ 56
Total compensation expense (after-tax)	65	83	40
Restricted stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense (pre-tax)	64	60	35
Performance shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense (pre-tax)	$ 27	$ 55	$ 21

COMMON STOCK AND SHARE-BASED _5

COMMON STOCK AND SHARE-BASED COMPENSATION (Summary of Stock Option Activity) (Details) - Employee Stock Option - $ / shares	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Number of Stock Options
Granted (in shares)	0	0
2014 LTIP
Number of Stock Options
Outstanding, beginning of period (in shares)	2,152,132
Granted (in shares)	0
Exercised (in shares)	0
Forfeited or expired (in shares)	(755,871)
Outstanding, end of period (in shares)	1,396,261	2,152,132
Vested or expected to vest (in shares)	1,396,261
Exercisable (in shares)	1,396,261
Weighted Average Grant- Date Fair Value
Outstanding, beginning of period (in dollars per share)	$ 7.36
Forfeited or expired (in dollars per share)	5.80
Outstanding, end of period (in dollars per share)	8.20	$ 7.36
Vested or expected to vest (in dollars per share)	8.20
Exercisable (in dollars per share)	$ 8.20
Weighted Average Remaining Contractual Term
Outstanding	2 years 3 months 14 days
Expected to vest	2 years 3 months 14 days
Exercisable	2 years 3 months 14 days

COMMON STOCK AND SHARE-BASED _6

COMMON STOCK AND SHARE-BASED COMPENSATION (Restricted Stock Units) (Details) - $ / shares	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Number of Restricted Stock Units
Nonvested, beginning balance (in shares)	10,978,120
Granted (in shares)	4,337,632
Vested (in shares)	(5,710,073)
Forfeited (in shares)	(337,254)
Nonvested, ending balance (in shares)	9,268,425	10,978,120
Weighted Average Grant- Date Fair Value
Nonvested, beginning balance (in dollars per share)	$ 11.21
Granted (in dollars per share)	15.70	$ 11.40	$ 11.01
Vested (in dollars per share)	11.16
Forfeited (in dollars per share)	12.77
Nonvested, ending balance (in dollars per share)	$ 13.29	$ 11.21

COMMON STOCK AND SHARE-BASED _7

COMMON STOCK AND SHARE-BASED COMPENSATION (Performance Shares) (Details) - Performance shares - $ / shares	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Number of Restricted Stock Units
Nonvested , beginning balance (in shares)	11,022,054
Granted (in shares)	4,881,031
Vested (in shares)	(8,049,294)
Forfeited (in shares)	(1,251,499)
Nonvested, ending balance (in shares)	6,602,292	11,022,054
Weighted Average Grant- Date Fair Value
Nonvested, beginning balance (in dollars per share)	$ 10.68
Granted (in dollars per share)	13.39	$ 13.44	$ 11.83
Vested (in dollars per share)	9.16
Forfeited (in dollars per share)	13.2
Nonvested, ending balance (in dollars per share)	$ 14.06	$ 10.68

PREFERRED STOCK (Details)

PREFERRED STOCK (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Jan. 31, 2022
Preferred Stock [Line Items]
Cumulative and unpaid dividends				$ 59
Pacific Gas & Electric Co (Utility)
Preferred Stock [Line Items]
Preferred stock dividends paid	$ 14	$ 70	$ 0
Pacific Gas & Electric Co (Utility) \| Minimum
Preferred Stock [Line Items]
Redemption price (in dollars per share)	$ 25.75	$ 25.75
Pacific Gas & Electric Co (Utility) \| Maximum
Preferred Stock [Line Items]
Redemption price (in dollars per share)	$ 27.25	$ 27.25
Pacific Gas & Electric Co (Utility) \| Nonredeemable Preferred Stock
Preferred Stock [Line Items]
Nonredeemable preferred stock outstanding	$ 145	$ 145
Preferred stock dividends per share, low range (in dollars per share)	$ 1.25
Preferred stock dividends per share, high range (in dollars per share)	$ 1.50
Pacific Gas & Electric Co (Utility) \| Nonredeemable Preferred Stock \| Minimum
Preferred Stock [Line Items]
Preferred stock interest rate	5%	5%
Pacific Gas & Electric Co (Utility) \| Nonredeemable Preferred Stock \| Maximum
Preferred Stock [Line Items]
Preferred stock interest rate	6%	6%
Pacific Gas & Electric Co (Utility) \| Redeemable Preferred Stock
Preferred Stock [Line Items]
Redeemable preferred stock outstanding	$ 113	$ 113
Preferred stock dividends per share, low range (in dollars per share)	$ 1.09
Preferred stock dividends per share, high range (in dollars per share)	$ 1.25
Pacific Gas & Electric Co (Utility) \| Redeemable Preferred Stock \| Minimum
Preferred Stock [Line Items]
Preferred stock interest rate	4.36%	4.36%
Pacific Gas & Electric Co (Utility) \| Redeemable Preferred Stock \| Maximum
Preferred Stock [Line Items]
Preferred stock interest rate	5%	5%
PG&E Corporation
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	400,000,000
Preferred stock, shares outstanding (in shares)	0
$25 Par Value \| Pacific Gas & Electric Co (Utility)
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	75,000,000
Preferred stock, par value (in dollars per share)	$ 25
$100 Par Value \| Pacific Gas & Electric Co (Utility)
Preferred Stock [Line Items]
Preferred stock, shares authorized (in shares)	10,000,000
Preferred stock, shares outstanding (in shares)	0
Preferred stock, par value (in dollars per share)	$ 100

EARNINGS PER SHARE (Reconciliat

EARNINGS PER SHARE (Reconciliation of PG&E Corporation's Income Available for Common Shareholders and Weighted Average Shares of Common Stock Outstanding for Calculating Diluted EPS) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Earnings Per Share [Abstract]
Income (loss) available for common shareholders	$ 2,242	$ 1,800	$ (102)
Weighted average common shares outstanding, basic (in shares)	2,064	1,987	1,985
Add incremental shares from assumed conversions:
Employee share-based compensation (in shares)	6	8	0
Equity Units (in shares)	68	137	0
Weighted average common share outstanding, diluted (in shares)	2,138	2,132	1,985
Total earnings (loss) per common share, diluted (in dollars per share)	$ 1.05	$ 0.84	$ (0.05)

INCOME TAXES (Schedule of Incom

INCOME TAXES (Schedule of Income Tax Provision (Benefit)) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Current:
Federal	$ (1)	$ (1)	$ 0
State	0	0	1
Deferred:
Federal	(1,047)	(943)	543
State	(507)	(389)	296
Tax credits	(2)	(5)	(4)
Income tax provision (benefit)	(1,557)	(1,338)	836
Pacific Gas & Electric Co (Utility)
Current:
Federal	(1)	(1)	0
State	0	0	0
Deferred:
Federal	(981)	(852)	588
State	(477)	(348)	316
Tax credits	(2)	(5)	(4)
Income tax provision (benefit)	$ (1,461)	$ (1,206)	$ 900

INCOME TAXES (Schedule of Defer

INCOME TAXES (Schedule of Deferred Tax Assets and Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Pacific Gas & Electric Co (Utility)
Deferred income tax assets:
Tax carryforwards	$ 8,740	$ 6,868
Compensation	82	80
GHG allowance	361	239
Wildfire-related claims	1,069	1,489
Operating lease liability	142	368
Transmission tower wireless licenses	250	254
Bad debt	134	55
Other	109	122
Total deferred income tax assets	10,887	9,475
Deferred income tax liabilities:
Property-related basis differences	10,047	9,363
Regulatory balancing accounts	1,433	1,376
Debt financing costs	428	465
Operating lease ROU asset	142	368
Income tax regulatory asset	991	764
Environmental reserve	200	163
Other	82	67
Total deferred income tax liabilities	13,323	12,566
Total net deferred income tax liabilities	2,436	3,091
PG&E Corporation
Deferred income tax assets:
Tax carryforwards	9,132	7,156
Compensation	145	157
GHG allowance	361	239
Wildfire-related claims	1,069	1,489
Operating lease liability	142	368
Transmission tower wireless licenses	250	254
Bad debt	134	55
Other	130	142
Total deferred income tax assets	11,363	9,860
Deferred income tax liabilities:
Property-related basis differences	10,058	9,374
Regulatory balancing accounts	1,433	1,376
Debt financing costs	428	465
Operating lease ROU asset	142	368
Income tax regulatory asset	991	764
Environmental reserve	200	163
Other	91	82
Total deferred income tax liabilities	13,343	12,592
Total net deferred income tax liabilities	$ 1,980	$ 2,732

INCOME TAXES (Schedule of Effec

INCOME TAXES (Schedule of Effective Income Tax Rate Reconciliation) (Details)	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Pacific Gas & Electric Co (Utility)
Operating Loss Carryforwards [Line Items]
Federal statutory income tax rate	21%	21%	21%
State income tax (net of federal benefit)	(34.40%)	(26.90%)	24.10%
Effect of regulatory treatment of fixed asset differences	(40.10%)	(49.20%)	(51.60%)
Tax credits	(2.20%)	(1.30%)	(1.20%)
Fire Victim Trust	(0.802)	(0.640)	0.919
Other, net	1.10%	2.20%	2.60%
Effective tax rate	(134.80%)	(118.20%)	86.80%
PG&E Corporation
Operating Loss Carryforwards [Line Items]
Federal statutory income tax rate	21%	21%	21%
State income tax (net of federal benefit)	(57.90%)	(75.80%)	31.30%
Effect of regulatory treatment of fixed asset differences	(63.40%)	(123.80%)	(71.50%)
Tax credits	(2.20%)	(3.20%)	(1.70%)
Fire Victim Trust	(1.269)	(1.609)	1.273
Other, net	2.20%	12.90%	5.30%
Effective tax rate	(227.20%)	(329.80%)	111.70%

INCOME TAXES (Schedule of Chang

INCOME TAXES (Schedule of Change in Unrecognized Tax Benefits) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Pacific Gas & Electric Co (Utility)
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance, beginning of period	$ 570	$ 498	$ 437
Additions for tax position taken during a prior year	1	0	0
Reductions for tax position taken during a prior year	0	(1)	(23)
Additions for tax position taken during the current year	45	73	85
Settlements	0	0	(1)
Balance, end of period	616	570	498
PG&E Corporation
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance, beginning of period	570	498	437
Additions for tax position taken during a prior year	1	0	0
Reductions for tax position taken during a prior year	0	(1)	(23)
Additions for tax position taken during the current year	45	73	85
Settlements	0	0	(1)
Balance, end of period	$ 616	$ 570	$ 498

INCOME TAXES (Narrative) (Detai

INCOME TAXES (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended	30 Months Ended
INCOME TAXES (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2023	Dec. 31, 2022
Investments, Owned, Federal Income Tax Note [Line Items]
Total UTB that, if recognized, would impact the effective income tax rate as of the end of the year	$ 33	$ 33
Income tax deduction, repair costs	850
Income tax deduction, customer bill credits	$ 400
Equity securities ownership, threshold	4.75%	4.75%
Common stock, shares outstanding (in shares)	2,133,597,758	2,133,597,758	1,987,784,948
Pacific Gas & Electric Co (Utility)
Investments, Owned, Federal Income Tax Note [Line Items]
Common stock, shares outstanding (in shares)	477,743,590	477,743,590
Fire Victim Trust
Investments, Owned, Federal Income Tax Note [Line Items]
Number of shares sold (in shares)		477,743,590
Shares sold, tax impact	$ 1,200	$ 2,000
Fire Victim Trust \| Pacific Gas & Electric Co (Utility)
Investments, Owned, Federal Income Tax Note [Line Items]
Common stock, shares outstanding (in shares)	247,743,590	247,743,590

INCOME TAXES (Summary of Operat

INCOME TAXES (Summary of Operating Loss and Tax Credit Carryforward) (Details) $ in Millions	Dec. 31, 2023 USD ($)
Federal
Operating Loss Carryforwards [Line Items]
Tax credit carryforward	$ 175
Federal \| Pre-2018
Operating Loss Carryforwards [Line Items]
Net operating loss carryforward	3,447
Federal \| Post-2017
Operating Loss Carryforwards [Line Items]
Net operating loss carryforward	29,403
State
Operating Loss Carryforwards [Line Items]
Net operating loss carryforward	32,583
Tax credit carryforward	$ 137

DERIVATIVES (Narrative) (Detail

DERIVATIVES (Narrative) (Details)	Dec. 31, 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)	Dec. 31, 2023 MMBTU MWh	Dec. 31, 2022 MMBTU MWh
Forwards, Futures and Swaps \| Natural Gas (MMBtus)
Derivative [Line Items]
Contract Volume	196,063,296	171,212,813
Forwards, Futures and Swaps \| Electricity (MWh)
Derivative [Line Items]
Contract Volume \| MWh	9,169,967	10,814,728
Options \| Natural Gas (MMBtus)
Derivative [Line Items]
Contract Volume	30,695,000	27,785,000
Options \| Electricity (MWh)
Derivative [Line Items]
Contract Volume	92,400	215,600
Congested Revenue Rights \| Electricity (MWh)
Derivative [Line Items]
Contract Volume \| MWh	170,465,674	205,743,505

DERIVATIVES (Outstanding Deriva

DERIVATIVES (Outstanding Derivative Balances) (Details) - Commodity Contract - Pacific Gas & Electric Co (Utility) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Derivatives And Hedging Activities [Line Items]
Netting	$ 82	$ 715
Netting	0	0
Cash Collateral	96	553
Total Derivative Balance	178	1,268
Current assets – other
Derivatives And Hedging Activities [Line Items]
Netting	134	824
Netting	(8)	(170)
Cash Collateral	50	537
Total Derivative Balance	176	1,191
Other noncurrent assets – other
Derivatives And Hedging Activities [Line Items]
Netting	280	306
Netting	0	0
Cash Collateral	0	0
Total Derivative Balance	280	306
Current liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Balance	(172)	(238)
Netting	8	170
Cash Collateral	46	16
Total Derivative Balance	(118)	(52)
Noncurrent liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Balance	(160)	(177)
Netting	0	0
Cash Collateral	0	0
Total Derivative Balance	$ (160)	$ (177)

FAIR VALUE MEASUREMENTS (Assets

FAIR VALUE MEASUREMENTS (Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Assets:
Price risk management instruments, netting	$ 42	$ 367
Price risk management instruments, assets	456	1,497
TOTAL ASSETS	5,501	7,127
Liabilities:
Price risk management instruments, netting	(54)	(186)
TOTAL LIABILITIES	278	229
Amount primarily related to deferred taxes on appreciation of investment value	717	575
Short-term investments
Assets:
Short-term investments	203	658
Fixed-income securities
Assets:
Short-term investments		49
Nuclear decommissioning trusts
Assets:
Short-term investments	52	117
Global equity securities	2,144	1,845
Fixed-income securities	2,077	1,885
TOTAL ASSETS	4,291	3,872
Customer credit trust
Assets:
Short-term investments	49	19
Global equity securities	71	218
Fixed-income securities	113	508
TOTAL ASSETS	233	745
Rabbi trusts
Assets:
Short-term investments	102	25
Global equity securities	5	5
Fixed-income securities		69
Life insurance contracts	65	64
TOTAL ASSETS	172	163
Long-term disability trust
Assets:
Short-term investments	7	10
TOTAL ASSETS	146	143
Electricity
Assets:
Price risk management instruments, netting	(1)	40
Price risk management instruments, assets	410	566
Liabilities:
Price risk management instruments, netting	(6)	(20)
Price risk management instruments, liabilities	250	223
Gas
Assets:
Price risk management instruments, netting	43	327
Price risk management instruments, assets	46	931
Liabilities:
Price risk management instruments, netting	(48)	(166)
Price risk management instruments, liabilities	28	6
Level 1
Assets:
Price risk management instruments, gross subject to netting	0	0
TOTAL ASSETS	3,830	4,207
Liabilities:
TOTAL LIABILITIES	0	0
Level 1 \| Short-term investments
Assets:
Short-term investments	203	658
Level 1 \| Fixed-income securities
Assets:
Short-term investments		0
Level 1 \| Nuclear decommissioning trusts
Assets:
Short-term investments	52	117
Global equity securities	2,144	1,845
Fixed-income securities	1,168	1,094
TOTAL ASSETS	3,364	3,056
Level 1 \| Customer credit trust
Assets:
Short-term investments	49	19
Global equity securities	71	218
Fixed-income securities	29	216
TOTAL ASSETS	149	453
Level 1 \| Rabbi trusts
Assets:
Short-term investments	102	25
Global equity securities	5	5
Fixed-income securities		0
Life insurance contracts	0	0
TOTAL ASSETS	107	30
Level 1 \| Long-term disability trust
Assets:
Short-term investments	7	10
TOTAL ASSETS	7	10
Level 1 \| 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 \| 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	10	698
TOTAL ASSETS	1,068	1,963
Liabilities:
TOTAL LIABILITIES	119	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	909	791
TOTAL ASSETS	909	791
Level 2 \| Customer credit trust
Assets:
Short-term investments	0	0
Global equity securities	0	0
Fixed-income securities	84	292
TOTAL ASSETS	84	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 \| Electricity
Assets:
Price risk management instruments, gross subject to netting	7	94
Liabilities:
Price risk management instruments, gross subject to netting	43	10
Level 2 \| Gas
Assets:
Price risk management instruments, gross subject to netting	3	604
Liabilities:
Price risk management instruments, gross subject to netting	76	172
Level 3
Assets:
Price risk management instruments, gross subject to netting	404	432
TOTAL ASSETS	404	432
Liabilities:
TOTAL LIABILITIES	213	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 \| Electricity
Assets:
Price risk management instruments, gross subject to netting	404	432
Liabilities:
Price risk management instruments, gross subject to netting	213	233
Level 3 \| Gas
Assets:
Price risk management instruments, gross subject to netting	0	0
Liabilities:
Price risk management instruments, gross subject to netting	0	0
Assets measured at NAV \| Nuclear decommissioning trusts
Assets:
Assets measured at NAV	18	25
Assets measured at NAV \| Long-term disability trust
Assets:
Assets measured at NAV	$ 139	$ 133

FAIR VALUE MEASUREMENTS (Level

FAIR VALUE MEASUREMENTS (Level 3 Measurements and Sensitivity Analysis) (Details) $ in Millions	Dec. 31, 2023 USD ($) $ / shares	Dec. 31, 2022 USD ($) $ / shares
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets \| $	$ 456	$ 1,497
Market approach \| Congested Revenue Rights
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets \| $	357	305
Liabilities \| $	134	138
Discounted cash flow \| Power purchase agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets \| $	47	127
Liabilities \| $	$ 79	$ 95
CRR auction prices \| Market approach \| Congested Revenue Rights \| Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range (in dollars per mwh)	(923.72)	(145.09)
CRR auction prices \| Market approach \| Congested Revenue Rights \| Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range (in dollars per mwh)	16,696.9	2,724.93
CRR auction prices \| Market approach \| Congested Revenue Rights \| Weighted average price
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range (in dollars per mwh)	1.43	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)	0.86	(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)	189.80	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)	60.03	78.14

FAIR VALUE MEASUREMENTS (Leve_2

FAIR VALUE MEASUREMENTS (Level 3 Reconciliation) (Details) - Level 3 - Price risk management instruments - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Asset (Liability) balance, beginning of period	$ 199	$ (34)
Included in regulatory assets and liabilities or balancing accounts	(8)	233
Asset balance, end of period	$ 191	$ 199

FAIR VALUE MEASUREMENTS (Carryi

FAIR VALUE MEASUREMENTS (Carrying Amount and Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Carrying Amount
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	$ 4,548	$ 4,355
Carrying Amount \| Convertible Notes Due 2027 \| Secured Debt
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	2,100
Carrying Amount \| Pacific Gas & Electric Co (Utility)
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	35,909	32,847
Level 2 \| Fair Value
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	4,695	4,490
Level 2 \| Fair Value \| Convertible Notes Due 2027 \| Secured Debt
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Debt financial instrument	2,200
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	$ 32,866	$ 27,666

FAIR VALUE MEASUREMENTS (Schedu

FAIR VALUE MEASUREMENTS (Schedule of Unrealized Gains Losses Related to Available-for-sale Investments) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Debt Securities, Available-for-sale [Line Items]
Amount primarily related to deferred taxes on appreciation of investment value	$ 717	$ 575
Nuclear decommissioning trusts
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	2,536	2,521
Total Unrealized Gains	1,852	1,478
Total Unrealized Losses	(97)	(127)
Total Fair Value	4,291	3,872
Nuclear decommissioning trusts \| Short-term investments
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	52	117
Total Unrealized Gains	0	0
Total Unrealized Losses	0	0
Total Fair Value	52	117
Nuclear decommissioning trusts \| Global equity securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	381	413
Total Unrealized Gains	1,792	1,468
Total Unrealized Losses	(11)	(11)
Total Fair Value	2,162	1,870
Nuclear decommissioning trusts \| Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	2,103	1,991
Total Unrealized Gains	60	10
Total Unrealized Losses	(86)	(116)
Total Fair Value	2,077	1,885
Customer credit trust
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	216	754
Total Unrealized Gains	18	13
Total Unrealized Losses	(1)	(22)
Total Fair Value	233	745
Customer credit trust \| Short-term investments
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	49	19
Total Unrealized Gains	0	0
Total Unrealized Losses	0	0
Total Fair Value	49	19
Customer credit trust \| Global equity securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	56	219
Total Unrealized Gains	16	13
Total Unrealized Losses	(1)	(14)
Total Fair Value	71	218
Customer credit trust \| Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	111	516
Total Unrealized Gains	2	0
Total Unrealized Losses	0	(8)
Total Fair Value	$ 113	$ 508

FAIR VALUE MEASUREMENTS (Sche_2

FAIR VALUE MEASUREMENTS (Schedule of Maturities on Debt Securities) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Nuclear decommissioning trusts
Debt Securities, Available-for-sale [Line Items]
Total maturities of fixed-income securities	$ 4,291	$ 3,872
Nuclear decommissioning trusts \| Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Less than 1 year	9
1–5 years	665
5–10 years	463
More than 10 years	940
Total maturities of fixed-income securities	2,077	1,885
Customer credit trust
Debt Securities, Available-for-sale [Line Items]
Total maturities of fixed-income securities	233	745
Customer credit trust \| Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Less than 1 year	0
1–5 years	25
5–10 years	29
More than 10 years	59
Total maturities of fixed-income securities	$ 113	$ 508

FAIR VALUE MEASUREMENTS (Sche_3

FAIR VALUE MEASUREMENTS (Schedule of Activity for Debt and Equity Securities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Proceeds from sales and maturities of nuclear decommissioning trust investments	$ 2,235	$ 3,316	$ 1,678
Nuclear decommissioning trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Proceeds from sales and maturities of nuclear decommissioning trust investments	2,235	3,316	1,678
Gross realized gains on securities	80	2	286
Gross realized losses on securities	(74)	(3)	$ (19)
Customer credit trust
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Proceeds from sales and maturities of nuclear decommissioning trust investments	556	250
Gross realized gains on securities	23	10
Gross realized losses on securities	(19)	(41)
Impairment write down	$ 4	$ 6

EMPLOYEE BENEFIT PLANS (Reconci

EMPLOYEE BENEFIT PLANS (Reconciliation of Changes in Plan Assets Benefit Obligations and Funded Status) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Funded Status:
Noncurrent liability	$ (476)	$ (231)
Pension Plan
Change in plan assets:
Fair value of plan assets at beginning of year	16,369	21,895
Actual return on plan assets	1,518	(4,916)
Company contributions	336	339
Benefits and expenses paid	(1,012)	(949)
Fair value of plan assets at end of year	17,211	16,369	$ 21,895
Change in benefit obligation:
Benefit obligation at beginning of year	16,608	22,759
Service cost for benefits earned	379	575	587
Interest cost	913	692	645
Actuarial loss/(gain)	809	(6,471)
Plan amendments	0	0
Benefits and expenses paid	(1,012)	(947)
Benefit obligation at end of year	17,697	16,608	22,759
Funded Status:
Current liability	(9)	(8)
Noncurrent liability	(477)	(231)
Net (liability) asset at end of year	(486)	(239)
Accumulated benefit obligation	16,300	15,400
PBOP Plans
Change in plan assets:
Fair value of plan assets at beginning of year	2,336	3,102
Actual return on plan assets	260	(693)
Company contributions	5	26
Plan participant contribution	81	81
Benefits and expenses paid	(183)	(180)
Fair value of plan assets at end of year	2,499	2,336	3,102
Change in benefit obligation:
Benefit obligation at beginning of year	1,339	1,766
Service cost for benefits earned	38	62	63
Interest cost	73	53	51
Actuarial loss/(gain)	8	(486)
Benefits and expenses paid	(165)	(162)
Federal subsidy on benefits paid	3	3
Plan participant contributions	81	81
VSP related termination benefits	0	22
Benefit obligation at end of year	1,377	1,339	$ 1,766
Funded Status:
Noncurrent asset	1,122	997
Noncurrent liability	0	0
Net (liability) asset at end of year	1,122	997
PBOP Plans \| Postretirement Life Insurance Plan
Change in plan assets:
Fair value of plan assets at beginning of year	266
Fair value of plan assets at end of year	292	266
Change in benefit obligation:
Benefit obligation at beginning of year	259
Benefit obligation at end of year	$ 275	$ 259

EMPLOYEE BENEFIT PLANS (Compone

EMPLOYEE BENEFIT PLANS (Components of Net Periodic Benefit Cost) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	$ 379	$ 575	$ 587
Interest cost	913	692	645
Expected return on plan assets	(981)	(1,189)	(1,046)
Amortization of prior service cost	(4)	(4)	(6)
Amortization of net actuarial gain (loss)	1	2	6
Net periodic benefit cost	308	76	186
Less: transfer to regulatory account	25	254	147
Total expense recognized	333	330	333
PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	38	62	63
Interest cost	73	53	51
Expected return on plan assets	(132)	(130)	(137)
Amortization of prior service cost	3	7	14
Amortization of net actuarial gain (loss)	(19)	(40)	(33)
Special termination benefits	0	22	0
Net periodic benefit cost	$ (37)	$ (26)	$ (42)

EMPLOYEE BENEFIT PLANS (Schedul

EMPLOYEE BENEFIT PLANS (Schedule of Assumptions Used in Calculating Projected Benefit Cost and Net Periodic Benefit Cost) (Details)	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	5.30%
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.21%	5.54%	3.03%
Rate of future compensation increases	3.80%	3.80%	3.80%
Expected return on plan assets	6%	6.10%	5.50%
Interest crediting rate for cash balance plan	3.86%	4.19%	1.95%
PBOP Plans \| Minimum
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.18%	5.50%	2.97%
Expected return on plan assets	3.70%	3.70%	3.30%
PBOP Plans \| Maximum
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.22%	5.54%	3.04%
Expected return on plan assets	7%	7.30%	6.40%

EMPLOYEE BENEFIT PLANS (Narrati

EMPLOYEE BENEFIT PLANS (Narrative) (Details) $ in Millions	12 Months Ended
EMPLOYEE BENEFIT PLANS (Narrative) (Details) $ in Millions	Dec. 31, 2023 USD ($) noncallable_bond	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Assumed health care cost trend rate	6.25%
Ultimate trend rate	4.50%
Assumed return	6%
10 year actual rate of return	5.30%
Number of Aa-grade non-callable bonds used to develop the yield curve for rate used (noncallable bond) \| noncallable_bond	858
Total fair value of trust other net liabilities	$ 10	$ 11
Retirement savings plan expense	$ 158	$ 144	$ 133
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
10 year actual rate of return	6%	6.10%	5.50%
Company contributions	$ 336	$ 339
Expected employer contribution next year	327
Long-term Disability Trusts
Defined Benefit Plan Disclosure [Line Items]
Company contributions	31
Expected employer contribution next year	31
PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
Company contributions	$ 5	$ 26

EMPLOYEE BENEFIT PLANS (Target

EMPLOYEE BENEFIT PLANS (Target Asset Allocation Percentages) (Details)	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		100%	100%
Pension Plan \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		26%	30%
Pension Plan \| Absolute return
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		1%	2%
Pension Plan \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		8%	8%
Pension Plan \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		65%	60%
PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		100%	100%
PBOP Plans \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		28%	26%
PBOP Plans \| Absolute return
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		1%	1%
PBOP Plans \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		3%	3%
PBOP Plans \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation		68%	70%
Forecast \| Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	100%
Forecast \| Pension Plan \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	26%
Forecast \| Pension Plan \| Absolute return
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	1%
Forecast \| Pension Plan \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	8%
Forecast \| Pension Plan \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	65%
Forecast \| PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	100%
Forecast \| PBOP Plans \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	29%
Forecast \| PBOP Plans \| Absolute return
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	0%
Forecast \| PBOP Plans \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	3%
Forecast \| PBOP Plans \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total target asset allocation	68%

EMPLOYEE BENEFIT PLANS (Sched_2

EMPLOYEE BENEFIT PLANS (Schedule of Fair Value of Plan Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	$ 19,720	$ 18,716
Level 3
Defined Benefit Plan Disclosure [Line Items]
Assets measured at NAV	13	8	$ 27
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	17,214	16,369
Assets measured at NAV	17,211	16,369	21,895
Pension Plan \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	651	587
Pension Plan \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1,270	1,430
Pension Plan \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	472	426
Pension Plan \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	8,741	8,040
Pension Plan \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	4,233	4,263
Pension Plan \| Level 1 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	565	461
Pension Plan \| Level 1 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1,270	1,430
Pension Plan \| Level 1 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	472	426
Pension Plan \| Level 1 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1,926	1,946
Pension Plan \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	6,888	6,212
Pension Plan \| Level 2 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	86	126
Pension Plan \| Level 2 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
Pension Plan \| Level 2 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
Pension Plan \| Level 2 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	6,802	6,086
Pension Plan \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	13	8
Pension Plan \| Level 3 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
Pension Plan \| Level 3 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
Pension Plan \| Level 3 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
Pension Plan \| Level 3 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	13	8
Pension Plan \| Assets measured at NAV
Defined Benefit Plan Disclosure [Line Items]
Assets measured at NAV	6,080	5,886
PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	2,506	2,347
Assets measured at NAV	2,499	2,336	$ 3,102
PBOP Plans \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	30	26
PBOP Plans \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	66	83
PBOP Plans \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	32	29
PBOP Plans \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1,218	1,109
PBOP Plans \| Level 1
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	550	544
PBOP Plans \| Level 1 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	30	26
PBOP Plans \| Level 1 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	66	83
PBOP Plans \| Level 1 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	32	29
PBOP Plans \| Level 1 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	422	406
PBOP Plans \| Level 2
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	795	702
PBOP Plans \| Level 2 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 2 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 2 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 2 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	795	702
PBOP Plans \| Level 3
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1	1
PBOP Plans \| Level 3 \| Short-term investments
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 3 \| Global equity securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 3 \| Real assets
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	0	0
PBOP Plans \| Level 3 \| Fixed-income securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1	1
PBOP Plans \| Assets measured at NAV
Defined Benefit Plan Disclosure [Line Items]
Assets measured at NAV	$ 1,160	$ 1,100

EMPLOYEE BENEFIT PLANS (Sched_3

EMPLOYEE BENEFIT PLANS (Schedule of Level 3 Reconciliation) (Details) - Level 3 - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Defined Benefit Plan, Change in Fair Value of Plan Assets, Level 3 Reconciliation [Roll Forward]
Fair value of plan assets at beginning of year	$ 8	$ 27
Actual return on plan assets:
Relating to assets still held at the reporting date	2	1
Relating to assets sold during the period	(1)	0
Purchases, issuances, sales, and settlements:
Purchases	10	6
Settlements	(6)	(26)
Fair value of plan assets at end of year	$ 13	$ 8

EMPLOYEE BENEFIT PLANS (Sched_4

EMPLOYEE BENEFIT PLANS (Schedule of Estimated Benefits Expected to Be Paid) (Details) $ in Millions	Dec. 31, 2023 USD ($)
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
2024	$ 957
2025	1,040
2026	1,066
2027	1,089
2028	1,111
Thereafter in the succeeding five years	5,802
PBOP Plans
Defined Benefit Plan Disclosure [Line Items]
2024	93
2025	93
2026	96
2027	87
2028	89
Thereafter in the succeeding five years	471
Federal Subsidy
Defined Benefit Plan Disclosure [Line Items]
2024	(4)
2025	(1)
2026	(1)
2027	(1)
2028	(1)
Thereafter in the succeeding five years	$ (4)

RELATED PARTY AGREEMENTS AND _3

RELATED PARTY AGREEMENTS AND TRANSACTIONS (Summary of Significant Related Party Transactions) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Related Party Transaction [Line Items]
Utility reveneus	$ 24,428	$ 21,680	$ 20,642
Utility expenses	21,757	19,843	18,759
Pacific Gas & Electric Co (Utility)
Related Party Transaction [Line Items]
Utility reveneus	24,428	21,680	20,642
Utility expenses	21,746	19,759	18,753
Pacific Gas & Electric Co (Utility) \| Administrative services provided to PG&E Corporation \| Related Party
Related Party Transaction [Line Items]
Utility reveneus	3	3	3
Pacific Gas & Electric Co (Utility) \| Administrative services received from PG&E Corporation \| Related Party
Related Party Transaction [Line Items]
Utility expenses	80	104	82
Pacific Gas & Electric Co (Utility) \| Utility employee benefit due to PG&E Corporation \| Related Party
Related Party Transaction [Line Items]
Utility expenses	$ 74	$ 85	$ 39

RELATED PARTY AGREEMENTS AND _4

RELATED PARTY AGREEMENTS AND TRANSACTIONS (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Related Party Transaction [Line Items]
Receivables	$ 1,494	$ 1,624
Accounts payable - other	851	778
Pacific Gas & Electric Co (Utility)
Related Party Transaction [Line Items]
Receivables	1,495	1,633
Accounts payable - other	820	747
Pacific Gas & Electric Co (Utility) \| Related Party
Related Party Transaction [Line Items]
Receivables	26	33
Accounts payable - other	$ 24	$ 46

WILDFIRE-RELATED CONTINGENCIE_2

WILDFIRE-RELATED CONTINGENCIES - Litigation Payments (Details) $ in Millions	Dec. 31, 2023 USD ($)
Loss Contingencies [Line Items]
Litigation payment	$ 1,803
2019 Kincade fire
Loss Contingencies [Line Items]
Litigation payment	667
2020 Zogg fire
Loss Contingencies [Line Items]
Litigation payment	390
2021 Dixie fire
Loss Contingencies [Line Items]
Litigation payment	731
2022 Mosquito fire
Loss Contingencies [Line Items]
Litigation payment	$ 15

WILDFIRE-RELATED CONTINGENCIE_3

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

3 Months Ended

12 Months Ended

Oct. 18, 2023 USD ($)

Jan. 05, 2022 USD ($)

Oct. 29, 2021 USD ($) a

Nov. 04, 2019 numberOfPeople

Dec. 31, 2023 USD ($)

Sep. 30, 2023 USD ($)

Dec. 31, 2023 USD ($)

Dec. 31, 2022 USD ($)

Feb. 14, 2024 numberOfClaimHolder complaint plaintiff notice

Oct. 09, 2023 USD ($)

Jan. 17, 2023 USD ($)

Sep. 06, 2022 a structure injury numberOfFatality

Aug. 31, 2022 USD ($)

Apr. 30, 2022 USD ($)

Jul. 13, 2021 a structure injury

Sep. 27, 2020 a structure fatality injury

Oct. 23, 2019 a numberOfFatality structure injury

2019 Kincade fire

Loss Contingencies [Line Items]

Number of acres burned (acre) | a

77,758

Number of fatalities (fatality) | numberOfFatality

Number of injuries | injury

Number of structures destroyed (structure) | structure

374

Number of structures damaged (structure) | structure

Number of people part of mandatory evacuation order | numberOfPeople

0.2

Fire fighting costs recovery requested

$ 90

Potential loss contingency

$ 100

$ 1,025

Loss contingency liability

1,125

$ 1,125

Insurance receivable

430

2020 Zogg fire

Loss Contingencies [Line Items]

Number of acres burned (acre) | a

56,338

Number of fatalities (fatality) | fatality

Number of injuries | injury

Number of structures destroyed (structure) | structure

204

Number of structures damaged (structure) | structure

Potential loss contingency

400

Insurance receivable

374

Liability insurance coverage

611

Initial self-insured retention per occurrence

Legal fees

Insurance Coverage for Wildfire Events

Loss Contingencies [Line Items]

Liability insurance coverage

$ 600

$ 340

Initial self-insured retention per occurrence

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

Potential loss contingency

$ 425

Loss contingency liability

$ 1,175

Insurance receivable

526

Liability insurance coverage

900

Number of residential structures destroyed (structure) | structure

763

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

Number of commercial residential structures destroyed (structure) | structure

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

Loss contingency approximate cost

$ 40

Loss contingency approximate cost, period

5 years

Estimated losses

1,600

Loss contingency, costs incurred

$ 650

Probable of recovery

1,687

2021 Dixie fire | California General Fund

Loss Contingencies [Line Items]

Settlement amount proposed

$ 2.5

$ 24

2021 Dixie fire | 2021 Dixie Fire, Tribes Impacted

Loss Contingencies [Line Items]

Settlement amount proposed

$ 2.5

2021 Dixie fire | Other Current Liabilities

Loss Contingencies [Line Items]

Potential loss contingency

2022 Mosquito fire

Loss Contingencies [Line Items]

Number of acres burned (acre) | a

76,788

Number of fatalities (fatality) | numberOfFatality

Number of injuries | injury

Number of structures destroyed (structure) | structure

Number of structures damaged (structure) | structure

Loss contingency liability

100

Insurance receivable

Liability insurance coverage

$ 733

733

Number of residential structures destroyed (structure) | structure

Number of detached structures destroyed (structure) | structure

Probable of recovery

123

Percentage of fire contained

100%

Subsequent Event | 2019 Kincade fire

Loss Contingencies [Line Items]

Number of complaints (complaint) | complaint

132

Number of plaintiffs represented by complaints | plaintiff

2,913

Subsequent Event | 2021 Dixie fire

Loss Contingencies [Line Items]

Number of complaints (complaint) | numberOfClaimHolder

161

Number of plaintiffs represented by complaints | numberOfClaimHolder

8,387

Subsequent Event | 2022 Mosquito fire

Loss Contingencies [Line Items]

Number of complaints (complaint) | complaint

Number of plaintiffs represented by complaints | notice

233

FERC TO rates | 2021 Dixie fire

Loss Contingencies [Line Items]

Probable of recovery

FERC TO rates | 2022 Mosquito fire

Loss Contingencies [Line Items]

Probable of recovery

WEMA | 2021 Dixie fire

Loss Contingencies [Line Items]

Probable of recovery

470

WEMA | 2022 Mosquito fire

Loss Contingencies [Line Items]

Probable of recovery

$ 52

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

WILDFIRE-RELATED CONTINGENCIE_4

WILDFIRE-RELATED CONTINGENCIES (Losses For Claims) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($)
2019 Kincade fire
Loss Contingency Accrual [Roll Forward]
Loss accrual, beginning balance	$ 650
Accrued Losses	100
Payments	(292)
Loss accrual, ending balance	458
2020 Zogg fire
Loss Contingency Accrual [Roll Forward]
Loss accrual, beginning balance	32
Accrued Losses	0
Payments	(22)
Loss accrual, ending balance	10
2021 Dixie fire
Loss Contingency Accrual [Roll Forward]
Loss accrual, beginning balance	1,131
Accrued Losses	425
Payments	(686)
Loss accrual, ending balance	870
2022 Mosquito fire
Loss Contingency Accrual [Roll Forward]
Loss accrual, beginning balance	99
Accrued Losses	0
Payments	(14)
Loss accrual, ending balance	$ 85

WILDFIRE-RELATED CONTINGENCIE_5

WILDFIRE-RELATED CONTINGENCIES (Loss Recoveries) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($)
2022 Mosquito fire
Loss Contingencies [Line Items]
Probable of recovery	$ 123
Probable of recovery, including legal costs	23
2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery	1,687
Probable of recovery, including legal costs	82
Insurance \| 2022 Mosquito fire
Loss Contingencies [Line Items]
Probable of recovery	63
Insurance \| 2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery	526
FERC TO rates \| 2022 Mosquito fire
Loss Contingencies [Line Items]
Probable of recovery	8
FERC TO rates \| 2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery	91
WEMA \| 2022 Mosquito fire
Loss Contingencies [Line Items]
Probable of recovery	52
WEMA \| 2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery	470
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	$ 600

WILDFIRE-RELATED CONTINGENCIE_6

WILDFIRE-RELATED CONTINGENCIES (Insurance Coverage) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Apr. 30, 2023	Aug. 01, 2023	Mar. 31, 2023	Dec. 31, 2023	Aug. 31, 2022	Apr. 30, 2022
Insurance Coverage for Wildfire Events
Loss Contingencies [Line Items]
Liability insurance coverage					$ 600	$ 340
Costs for insurance coverage		$ 516	$ 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 Non-Wildfire Liabilities
Loss Contingencies [Line Items]
Liability insurance coverage	$ 710
Costs for insurance coverage	167
Initial self-insured retention per occurrence	$ 10
Prepaid insurance				$ 61

WILDFIRE-RELATED CONTINGENCIE_7

WILDFIRE-RELATED CONTINGENCIES (Self-Insurance) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
CPUC
Loss Contingencies [Line Items]
Self insurance rate		$ 400
Increase in self insurance amount to be collected, percentage		50%
Self insurance deductible, percent		0.05
Self insurance deductible maximum		$ 50
CPUC \| Forecast
Loss Contingencies [Line Items]
Self insurance rate	$ 1,000
TO21
Loss Contingencies [Line Items]
Self insurance rate		100
PERS
Loss Contingencies [Line Items]
Self insurance contributions		340
Self insurance contributions, minimum capital and surplus requirements		$ 8

WILDFIRE-RELATED CONTINGENCIE_8

WILDFIRE-RELATED CONTINGENCIES (Insurance Receivable) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($)
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	$ 794
Accrued insurance recoveries	18
Reimbursements	(376)
Insurance Receivable, Ending Balance	436
2022 Mosquito fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	45
Accrued insurance recoveries	18
Reimbursements	0
Insurance Receivable, Ending Balance	63
Insurance receivable	63
2021 Dixie fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	530
Accrued insurance recoveries	(4)
Reimbursements	(200)
Insurance Receivable, Ending Balance	326
Insurance receivable	526
2020 Zogg fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	118
Accrued insurance recoveries	4
Reimbursements	(75)
Insurance Receivable, Ending Balance	47
Insurance receivable	374
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_9

WILDFIRE-RELATED CONTINGENCIES (Regulatory Recovery) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($)
2021 Dixie fire
Loss Contingencies [Line Items]
Probable of recovery	$ 1,687
2021 Dixie fire \| FERC TO rates
Loss Contingencies [Line Items]
Probable of recovery	91
2021 Dixie fire \| WEMA
Loss Contingencies [Line Items]
Probable of recovery	470
2022 Mosquito fire
Loss Contingencies [Line Items]
Probable of recovery	123
2022 Mosquito fire \| FERC TO rates
Loss Contingencies [Line Items]
Probable of recovery	8
2022 Mosquito fire \| WEMA
Loss Contingencies [Line Items]
Probable of recovery	$ 52

WILDFIRE-RELATED CONTINGENCI_10

WILDFIRE-RELATED CONTINGENCIES (Wildfire Fund) (Details) - USD ($) $ in Millions	Aug. 23, 2019	Dec. 31, 2023	Dec. 31, 2022
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
Insurance receivable		436	$ 794
2021 Dixie fire
Loss Contingencies [Line Items]
Insurance receivable		326	$ 530
2021 Dixie fire \| Other noncurrent assets – other
Loss Contingencies [Line Items]
Insurance receivable		325
2021 Dixie fire \| Other noncurrent assets – other \| Pacific Gas & Electric Co (Utility)
Loss Contingencies [Line Items]
Insurance receivable		$ 275

WILDFIRE-RELATED CONTINGENCI_11

WILDFIRE-RELATED CONTINGENCIES (Wildfire-Related Securities Securities Litigation and Claims in District Court) (Details) - Wildfire-Related Class Action $ in Millions	Dec. 31, 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_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	Mar. 17, 2022	Dec. 20, 2018	Dec. 31, 2023
Transmission Owner Rate Case Revenue
Loss Contingencies [Line Items]
Regulatory liabilities			$ 484
Regulatory assets			$ 233
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 (Interim Rate Relief Subject to Refund) (Details) - WMCE Interim Rate Relief - Pacific Gas & Electric Co (Utility) $ in Millions	Dec. 15, 2022 USD ($)
Loss Contingencies [Line Items]
Cost recovery	$ 1,360
Interim revenue requirement	1,290
Recorded expenditures, expenses	1,200
Recorded expenditures, capital expenditures	136
Interim rate relief	1,100
Remaining value recoverable	$ 224

OTHER CONTINGENCIES AND COMMI_5

OTHER CONTINGENCIES AND COMMITMENTS (Other Matters) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Accrued legal liabilities	$ 89	$ 69

OTHER CONTINGENCIES AND COMMI_6

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_7

OTHER CONTINGENCIES AND COMMITMENTS (Schedule Environmental Remediation Liability Composed) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Disclosure Commitments And Contingencies Environmental Remediation Liability Composed [Abstract]
Topock natural gas compressor station	$ 276	$ 284
Hinkley natural gas compressor station	104	110
Former manufactured gas plant sites owned by the Utility or third parties	809	750
Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites	107	112
Fossil fuel-fired generation facilities and sites	19	26
Total environmental remediation liability	$ 1,315	$ 1,282

OTHER CONTINGENCIES AND COMMI_8

OTHER CONTINGENCIES AND COMMITMENTS (Environmental Remediation Contingencies Narrative) (Details) $ in Millions	Dec. 31, 2023 USD ($)
Long-term Purchase Commitment [Line Items]
Amount of environmental loss accrual expected to be recovered	$ 1,100
Topock Site
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 216
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	$ 128
Former Manufactured Gas Plant
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 579
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	$ 82
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	$ 43

OTHER CONTINGENCIES AND COMMI_9

OTHER CONTINGENCIES AND COMMITMENTS (Nuclear Insurance and Purchase Commitments) (Details)	12 Months Ended
	Dec. 31, 2023 USD ($) nuclear_generating_unit
Long-term Purchase Commitment [Line Items]
Number of nuclear generating units (nuclear generating unit) \| nuclear_generating_unit	2
Maximum total payment incurred per event under the loss sharing program	$ 450,000,000
Nuclear Electric Insurance Limited and European Mutual Association for Nuclear Insurance
Long-term Purchase Commitment [Line Items]
Insurance coverage, loss	400,000,000
Humboldt Bay Unit
Long-term Purchase Commitment [Line Items]
Amount of property damage coverage provided by NEIL	50,000,000
Amount of liability insurance for Humboldt Bay Unit 3	53,000,000
Diablo Canyon
Long-term Purchase Commitment [Line Items]
Maximum public liability per nuclear incident under Price-Anderson Act	16,300,000,000
Maximum available public liability insurance for Diablo Canyon as required by Price-Anderson Act	450,000,000
Maximum annual payment incurred per event under the loss sharing program	332,000,000
Maximum annual payment incurred per event under the loss sharing program	$ 49,000,000
Period for inflation adjustment	5 years
Nuclear Incident
Long-term Purchase Commitment [Line Items]
Amount of property damage and business interruption coverage provided by NEIL for Diablo Canyon	$ 3,200,000,000
Nuclear Incident \| Humboldt Bay Unit
Long-term Purchase Commitment [Line Items]
Amount of indemnification from the nuclear regulatory commission for public liability arising from nuclear incidents	450,000,000
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	4,000,000
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 (Schedule of Purchase Commitments) (Details) $ in Millions	Dec. 31, 2023 USD ($)
Long-term Purchase Commitment [Line Items]
2024	$ 3,371
2025	3,187
2026	3,099
2027	2,750
2028	2,552
Thereafter	17,186
Total purchase commitments	32,145
Renewable Energy
Long-term Purchase Commitment [Line Items]
2024	2,005
2025	1,995
2026	1,935
2027	1,883
2028	1,827
Thereafter	15,676
Total purchase commitments	25,321
Conventional Energy
Long-term Purchase Commitment [Line Items]
2024	481
2025	819
2026	766
2027	682
2028	683
Thereafter	1,501
Total purchase commitments	4,932
Natural Gas
Long-term Purchase Commitment [Line Items]
2024	584
2025	171
2026	123
2027	53
2028	0
Thereafter	0
Total purchase commitments	931
Other
Long-term Purchase Commitment [Line Items]
2024	301
2025	202
2026	275
2027	132
2028	41
Thereafter	9
Total purchase commitments	$ 960

OTHER CONTINGENCIES AND COMM_11

OTHER CONTINGENCIES AND COMMITMENTS (Third-Party Power Purchase Agreements and Other Agreements) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Power Purchases and Electric Capacity
Third-Party Power Purchase Agreements [Line Items]
Costs incurred for power purchases and electric capacity	$ 2,400	$ 2,800	$ 3,000
Nuclear Fuel
Third-Party Power Purchase Agreements [Line Items]
Payments for nuclear fuel	180	44	79
Gas Contracts
Third-Party Power Purchase Agreements [Line Items]
Cost of goods	$ 2,500	$ 2,400	$ 1,200

OTHER CONTINGENCIES AND COMM_12

OTHER CONTINGENCIES AND COMMITMENTS (Schedule of Other Commitments) (Details) $ in Millions	Dec. 31, 2023 USD ($)
Commitments and Contingencies Disclosure [Abstract]
2024	$ 55
2025	29
2026	2
2027	0
2028	0
Thereafter	0
Total minimum lease payments	$ 86

OTHER CONTINGENCIES AND COMM_13

OTHER CONTINGENCIES AND COMMITMENTS (Other Commitments) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2040	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Jun. 30, 2025	Jul. 11, 2024	Jul. 11, 2023
Operating Leased Assets [Line Items]
Payments for other commitments		$ 106	$ 63	$ 50
Oakland Headquarters Lease \| Pacific Gas & Electric Co (Utility)
Operating Leased Assets [Line Items]
Purchase price							$ 906
Purchase price, deposits							$ 150
Oakland Headquarters Lease \| Pacific Gas & Electric Co (Utility) \| Forecast
Operating Leased Assets [Line Items]
Purchase price, deposits					$ 506	$ 250
SB 901 Securitization \| Secured Debt
Operating Leased Assets [Line Items]
Shareholder contribution amount		$ 1,000
SB 901 Securitization \| Secured Debt \| Forecast
Operating Leased Assets [Line Items]
Shareholder contribution amount	$ 775
Minimum
Operating Leased Assets [Line Items]
Extension option for operating leases		1 year
Maximum
Operating Leased Assets [Line Items]
Extension option for operating leases		5 years

SCHEDULE I _ CONDENSED FINANC_2

SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT (Schedule of Condensed Income Statement and Comprehensive Income) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Operating expenses	$ (21,757)	$ (19,843)	$ (18,759)
Interest income	606	162	20
Interest expense	(2,850)	(1,917)	(1,601)
Other income, net	272	394	457
Reorganization Items	0	0	(11)
Income tax provision (benefit)	(1,557)	(1,338)	836
Income Available for Common Shareholders	2,242	1,800	(102)
Other Comprehensive Income (Loss)
Pension and other postretirement benefit plans obligations (net of taxes of $6, $8, and $3, at respective dates)	(16)	21	7
Total other comprehensive income (loss)	$ (8)	$ 15	$ 7
Weighted Average Common Shares Outstanding, Basic (in shares)	2,064,000,000	1,987,000,000	1,985,000,000
Weighted Average Common Shares Outstanding, Diluted (in shares)	2,138,000,000	2,132,000,000	1,985,000,000
Net earnings (loss) per common share, basic (in dollars per share)	$ 1.09	$ 0.91	$ (0.05)
Net earnings (loss) per common share, diluted (in dollars per share)	$ 1.05	$ 0.84	$ (0.05)
Pension and other postretirement benefit plans obligations, tax	$ 6	$ 8	$ 3
Treasury stock, shares at cost (in shares)	0	247,743,590
PG&E Corporation
Operating expenses	$ (165)	$ (193)	(124)
Interest income	13	3	0
Interest expense	(365)	(261)	(230)
Other income, net	(21)	(201)	(54)
Reorganization Items	0	0	1
Equity in earnings of subsidiaries	2,530	2,154	137
Income (loss) before income taxes	2,146	1,611	(152)
Income tax provision (benefit)	(96)	(132)	(64)
Income Available for Common Shareholders	2,242	1,743	(88)
Other Comprehensive Income (Loss)
Pension and other postretirement benefit plans obligations (net of taxes of $6, $8, and $3, at respective dates)	(16)	21	7
Total other comprehensive income (loss)	(16)	21	7
Comprehensive Income (Loss)	$ 2,226	$ 1,764	$ (81)
Weighted Average Common Shares Outstanding, Basic (in shares)	2,064,000,000	2,235,000,000	2,463,000,000
Weighted Average Common Shares Outstanding, Diluted (in shares)	2,138,000,000	2,380,000,000	2,463,000,000
Net earnings (loss) per common share, basic (in dollars per share)	$ 1.09	$ 0.78	$ (0.05)
Net earnings (loss) per common share, diluted (in dollars per share)	$ 1.05	$ 0.73	$ (0.05)
Pension and other postretirement benefit plans obligations, tax	$ 6	$ 8	$ 3
PG&E Corporation \| Administrative service revenue
Administrative service revenue	$ 154	$ 109	$ 118

SCHEDULE I _ CONDENSED FINANC_3

SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT (Schedule of Condensed Balance Sheet) (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Current Assets
Cash and cash equivalents	$ 635	$ 734	$ 291
Restricted cash	297	213
Receivables	1,494	1,624
Other	1,375	1,433
Total current assets	14,383	12,815
Noncurrent Assets
TOTAL ASSETS	125,698	118,644
Current Liabilities
Long-term debt, classified as current (includes $176 million and $168 million related to VIEs at respective dates)	1,376	2,268
Other current liabilities	4,698	3,372
Total current liabilities	17,314	15,788
Noncurrent Liabilities
Long-term debt	50,975	47,742
Other	3,633	4,291
Total noncurrent liabilities	83,092	79,781
Common Shareholders’ Equity
Common stock, no par value, authorized 3,600,000,000 and 3,600,000,000 shares at respective dates; 2,133,597,758 and 1,987,784,948 shares outstanding at respective dates	30,374	32,887
Reinvested earnings	(5,321)	(7,542)
Accumulated other comprehensive income (loss)	(13)	(5)
Total shareholders’ equity	25,040	22,823
TOTAL LIABILITIES AND EQUITY	125,698	118,644
PG&E Corporation
Current Assets
Cash and cash equivalents	192	125	$ 126
Restricted cash	3	0
Receivables	24	46
Income taxes receivable	2	10
Other	1	12
Total current assets	222	193
Noncurrent Assets
Investments in subsidiaries	36,804	33,021
Other investments	167	160
Deferred income taxes	539	423
Total noncurrent assets	37,510	33,604
TOTAL ASSETS	37,732	33,797
Current Liabilities
Long-term debt, classified as current (includes $176 million and $168 million related to VIEs at respective dates)	0	27
Accounts payable – other	58	88
Income taxes payable	1	0
Other current liabilities	363	369
Total current liabilities	422	484
Noncurrent Liabilities
Long-term debt	4,599	4,588
Other	141	134
Total noncurrent liabilities	4,740	4,722
Common Shareholders’ Equity
Common stock, no par value, authorized 3,600,000,000 and 3,600,000,000 shares at respective dates; 2,133,597,758 and 1,987,784,948 shares outstanding at respective dates	37,906	36,132
Reinvested earnings	(5,322)	(7,542)
Accumulated other comprehensive income (loss)	(14)	1
Total shareholders’ equity	32,570	28,591
TOTAL LIABILITIES AND EQUITY	$ 37,732	$ 33,797

SCHEDULE I _ CONDENSED FINANC_4

SCHEDULE I – CONDENSED FINANCIAL INFORMATION OF PARENT (Schedule of Condensed Statement of Cash Flows) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash Flows from Operating Activities
Net Income (Loss)		$ 2,256	$ 1,814	$ (88)
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income taxes and tax credits, net		(765)	(452)	1,783
Reorganization items, net		0	0	(73)
Net cash provided by operating activities		4,747	3,721	2,262
Cash Flows from Investing Activities
Net cash used in investing activities		(9,162)	(10,214)	(6,905)
Cash Flows From Financing Activities:
Proceeds from issuance of convertible notes, net of discount and issuance costs of $27, $0, and $0 at respective dates		2,123	0	0
Premium, discount, and issuance costs on proceeds from long-term debt		67	29	33
Repayments of long-term debt		(3,075)	(5,968)	(87)
Repayments under term loan credit facilities		(10,540)	(9,750)	(9,976)
Other		(17)	53	(29)
Net cash provided by financing activities		4,400	7,133	4,323
Net change in cash, cash equivalents, and restricted cash		(15)	640	(320)
Cash, cash equivalents, and restricted cash at January 1		947	307	627
Cash, cash equivalents, and restricted cash at September 30		932	947	307
Less: Restricted cash and restricted cash equivalents		(297)	(213)	(16)
Cash and cash equivalents		635	734	291
Cash paid for:
Interest, net of amounts capitalized		(2,286)	(1,607)	(1,404)
Income taxes, net		0	0	(99)
Noncash Investing and Financing Items [Abstract]
Changes to PG&E Corporation common stock and treasury stock in connection with the Share Exchange and Tax Matters Agreement		(2,517)	(2,337)	4,854
Common stock dividends declared but not yet paid		21	0	0
PG&E Corporation
Cash Flows from Operating Activities
Net Income (Loss)		2,242	1,743	(88)
Adjustments to reconcile net income to net cash provided by operating activities:
Stock-based compensation amortization		4	95	51
Equity in earnings of subsidiaries		(2,530)	(2,160)	(139)
Deferred income taxes and tax credits, net		(116)	(126)	(60)
Reorganization items, net		0	0	(32)
Current income taxes receivable/payable		9	0	2
Other		40	339	81
Net cash provided by operating activities		(351)	(109)	(185)
Cash Flows from Investing Activities
Investment in subsidiaries		(1,290)	(994)	0
Dividends received from subsidiaries	[1]	1,775	1,275	0
Net cash used in investing activities		485	281	0
Cash Flows From Financing Activities:
Proceeds from issuance of convertible notes, net of discount and issuance costs of $27, $0, and $0 at respective dates		2,123	0	0
Premium, discount, and issuance costs on proceeds from long-term debt		27	0	0
Repayments of long-term debt		0	(28)	(28)
Intercompany note to PG&E Corporation		0	(145)	145
Repayments under term loan credit facilities		(2,181)	0	0
Other		(6)	0	(29)
Net cash provided by financing activities		(64)	(173)	88
Net change in cash, cash equivalents, and restricted cash		70	(1)	(97)
Cash, cash equivalents, and restricted cash at January 1		125	126	223
Cash, cash equivalents, and restricted cash at September 30		195	125	126
Less: Restricted cash and restricted cash equivalents		(3)	0	0
Cash and cash equivalents		192	125	126
Cash paid for:
Interest, net of amounts capitalized		(309)	(233)	(207)
Income taxes, net		0	0	1
Noncash Investing and Financing Items [Abstract]
Changes to PG&E Corporation common stock and treasury stock in connection with the Share Exchange and Tax Matters Agreement		(2,517)	(2,337)	4,854
Common stock dividends declared but not yet paid		$ 21	$ 0	$ 0

[1] Because of its nature as a holding company, PG&E Corporation classifies dividends received from subsidiaries as an investing cash flow.

SCHEDULE II _ CONSOLIDATED VA_2

SCHEDULE II – CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$ 166	$ 171	$ 146
Charged to Costs and Expenses	624	146	136
Charged to Other Accounts	0	0	0
Deductions	345	151	111
Balance at End of Period	$ 445	$ 166	$ 171