PG&E (PCG) 10-Q 30 Jul 20 2020 Q2 Quarterly report Financial data

Cover Page

Cover Page - shares	6 Months Ended
	Jun. 30, 2020	Jul. 27, 2020
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2020
Document Transition Report	false
Entity File Number	1-12609
Entity Registrant Name	PG&E CORP
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	94-3234914
Entity Address, Address Line One	77 Beale Street
Entity Address, Address Line Two	P.O. Box 770000
Entity Address, City or Town	San Francisco,
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	94177
City Area Code	415
Local Phone Number	973-1000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)		1,941,473,377
Amendment Flag	false
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q2
Entity Central Index Key	0001004980
Current Fiscal Year End Date	--12-31
Pacific Gas & Electric Co
Entity Information [Line Items]
Entity File Number	1-2348
Entity Registrant Name	PACIFIC GAS & ELECTRIC CO
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	94-0742640
Entity Address, Address Line One	77 Beale Street
Entity Address, Address Line Two	P.O. Box 770000
Entity Address, City or Town	San Francisco,
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	94177
City Area Code	415
Local Phone Number	973-7000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)		264,374,809
Amendment Flag	false
Entity Central Index Key	0000075488
The New York Stock Exchange | Common stock, no par value
Entity Information [Line Items]
Title of 12(b) Security	Common stock, no par value
Trading Symbol	PCG
Security Exchange Name	NYSE
The New York Stock Exchange | Equity Units
Entity Information [Line Items]
Title of 12(b) Security	Equity Units
Trading Symbol	PCGU
Security Exchange Name	NYSE
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 5% series A redeemable
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 5% series A redeemable
Trading Symbol	PCG-PE
Security Exchange Name	NYSEAMER
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 5% redeemable
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 5% redeemable
Trading Symbol	PCG-PD
Security Exchange Name	NYSEAMER
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 4.80% redeemable
Entity Information [Line Items]
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
Entity Information [Line Items]
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
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 4.36% series A redeemable
Trading Symbol	PCG-PI
Security Exchange Name	NYSEAMER
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 6% nonredeemable
Entity Information [Line Items]
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
Entity Information [Line Items]
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
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 5% nonredeemable
Trading Symbol	PCG-PC
Security Exchange Name	NYSEAMER

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Operating Revenues
Total operating revenues	$ 4,533	$ 3,943	$ 8,839	$ 7,954
Operating Expenses
Operating and maintenance	2,141	1,942	4,108	4,029
Wildfire-related claims, net of insurance recoveries	170	3,900	170	3,900
Wildfire fund expense	173	0	173	0
Depreciation, amortization, and decommissioning	874	796	1,729	1,593
Total operating expenses	4,251	7,583	7,902	11,405
Operating Income (Loss)	282	(3,640)	937	(3,451)
Interest income	12	22	28	44
Interest expense	(199)	(60)	(453)	(163)
Other income, net	100	66	197	137
Reorganization items, net	(1,624)	(56)	(1,800)	(183)
Income (Loss) Before Income Taxes	(1,429)	(3,668)	(1,091)	(3,616)
Income tax provision (benefit)	539	(1,119)	503	(1,203)
Net Loss	(1,968)	(2,549)	(1,594)	(2,413)
Preferred stock dividend requirement of subsidiary	4	4	7	7
Loss Attributable to Common Shareholders	$ (1,972)	$ (2,553)	$ (1,601)	$ (2,420)
Weighted Average Common Shares Outstanding, Basic (in shares)	529	529	529	528
Weighted Average Common Shares Outstanding, Diluted (in shares)	529	529	529	528
Net Loss Per Common Share, Basic (in dollars per share)	$ (3.73)	$ (4.83)	$ (3.03)	$ (4.58)
Net Loss Per Common Share, Diluted (in dollars per share)	$ (3.73)	$ (4.83)	$ (3.03)	$ (4.58)
Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	$ 4,533	$ 3,943	$ 8,839	$ 7,954
Operating Expenses
Operating and maintenance	2,145	1,940	4,110	4,044
Wildfire-related claims, net of insurance recoveries	170	3,900	170	3,900
Wildfire fund expense	173	0	173	0
Depreciation, amortization, and decommissioning	874	796	1,729	1,593
Total operating expenses	4,255	7,581	7,904	11,420
Operating Income (Loss)	278	(3,638)	935	(3,466)
Interest income	12	22	28	43
Interest expense	(189)	(60)	(441)	(161)
Other income, net	93	64	186	130
Reorganization items, net	(111)	(57)	(204)	(168)
Income (Loss) Before Income Taxes	83	(3,669)	504	(3,622)
Income tax provision (benefit)	556	(1,119)	526	(1,205)
Net Loss	(473)	(2,550)	(22)	(2,417)
Preferred stock dividend requirement of subsidiary	4	4	7	7
Loss Attributable to Common Shareholders	(477)	(2,554)	(29)	(2,424)
Electric
Operating Revenues
Total operating revenues	3,435	2,946	6,475	5,738
Operating Expenses
Cost of goods	759	837	1,304	1,436
Electric | Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	3,435	2,946	6,475	5,738
Operating Expenses
Cost of goods	759	837	1,304	1,436
Natural gas
Operating Revenues
Total operating revenues	1,098	997	2,364	2,216
Operating Expenses
Cost of goods	134	108	418	447
Natural gas | Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	1,098	997	2,364	2,216
Operating Expenses
Cost of goods	$ 134	$ 108	$ 418	$ 447

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Net Loss	$ (1,968)	$ (2,549)	$ (1,594)	$ (2,413)
Other Comprehensive Income
Pension and other post-retirement benefit plans obligations (net of taxes of $0, $0, $0, and $0, at respective dates)	0	0	0	0
Total other comprehensive income	0	0	0	0
Comprehensive Loss	(1,968)	(2,549)	(1,594)	(2,413)
Preferred stock dividend requirement of subsidiary	4	4	7	7
Comprehensive Loss Attributable to Common Shareholders	(1,972)	(2,553)	(1,601)	(2,420)
Pacific Gas & Electric Co
Net Loss	(473)	(2,550)	(22)	(2,417)
Other Comprehensive Income
Pension and other post-retirement benefit plans obligations (net of taxes of $0, $0, $0, and $0, at respective dates)	0	0	0	0
Total other comprehensive income	0	0	0	0
Comprehensive Loss	$ (473)	$ (2,550)	$ (22)	$ (2,417)

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Pension and other postretirement benefit plans obligations tax	$ 0	$ 0	$ 0	$ 0
Pacific Gas & Electric Co
Pension and other postretirement benefit plans obligations tax	$ 0	$ 0	$ 0	$ 0

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Current Assets
Cash and cash equivalents	$ 968	$ 1,570
Restricted cash	14,413	7
Accounts receivable:
Customers (net of allowance for doubtful accounts of $81 and $43 at respective dates)	1,419	1,287
Accrued unbilled revenue	1,061	969
Regulatory balancing accounts	2,638	2,114
Other	2,618	2,617
Regulatory assets	377	315
Inventories:
Gas stored underground and fuel oil	89	97
Materials and supplies	564	550
Wildfire fund asset	466	0
Other	400	639
Total current assets	25,013	10,165
Property, Plant, and Equipment
Electric	64,832	62,707
Gas	23,371	22,688
Construction work in progress	2,615	2,675
Other	20	20
Total property, plant, and equipment	90,838	88,090
Accumulated depreciation	(27,437)	(26,455)
Net property, plant, and equipment	63,401	61,635
Other Noncurrent Assets
Regulatory assets	7,507	6,066
Nuclear decommissioning trusts	3,196	3,173
Operating lease right of use asset	2,127	2,286
Wildfire fund asset	6,048	0
Income taxes receivable	67	67
Other	1,870	1,804
Total other noncurrent assets	20,815	13,396
TOTAL ASSETS	109,229	85,196
Current Liabilities
Short-term borrowings	300	0
Long-term debt, classified as current	450	0
Debtor-in-possession financing, classified as current	2,000	1,500
Accounts payable:
Trade creditors	3,399	1,954
Regulatory balancing accounts	1,915	1,797
Other	631	566
Operating lease liabilities	551	556
Interest payable	1,363	4
Disputed claims and customer refunds	238	0
Wildfire-related Claims	26,143	0
Wildfire fund liability	5,200	0
Other	3,605	1,254
Total current liabilities	45,795	7,631
Noncurrent Liabilities
Long-term debt	34,920	0
Regulatory liabilities	9,641	9,270
Pension and other post-retirement benefits	1,941	1,884
Asset retirement obligations	5,961	5,854
Deferred income taxes	1,171	320
Operating lease liabilities	1,576	1,730
Other	4,423	2,573
Total noncurrent liabilities	59,633	21,631
Liabilities Subject to Compromise	0	50,546
Shareholders’ Equity
Common stock	13,045	13,038
Reinvested earnings	(9,486)	(7,892)
Accumulated other comprehensive loss	(10)	(10)
Total shareholders’ equity	3,549	5,136
Noncontrolling Interest - Preferred Stock of Subsidiary	252	252
Total equity	3,801	5,388
TOTAL LIABILITIES AND EQUITY	109,229	85,196
Pacific Gas & Electric Co
Current Assets
Cash and cash equivalents	746	1,122
Restricted cash	9,076	7
Accounts receivable:
Customers (net of allowance for doubtful accounts of $81 and $43 at respective dates)	1,419	1,287
Accrued unbilled revenue	1,061	969
Regulatory balancing accounts	2,638	2,114
Other	2,634	2,647
Regulatory assets	377	315
Inventories:
Gas stored underground and fuel oil	89	97
Materials and supplies	564	550
Wildfire fund asset	466	0
Other	388	628
Total current assets	19,458	9,736
Property, Plant, and Equipment
Electric	64,832	62,707
Gas	23,371	22,688
Construction work in progress	2,615	2,675
Other	18	18
Total property, plant, and equipment	90,836	88,088
Accumulated depreciation	(27,435)	(26,453)
Net property, plant, and equipment	63,401	61,635
Other Noncurrent Assets
Regulatory assets	7,507	6,066
Nuclear decommissioning trusts	3,196	3,173
Operating lease right of use asset	2,121	2,279
Wildfire fund asset	6,048	0
Income taxes receivable	66	66
Other	1,714	1,659
Total other noncurrent assets	20,652	13,243
TOTAL ASSETS	103,511	84,614
Current Liabilities
Long-term debt, classified as current	100	0
Debtor-in-possession financing, classified as current	2,000	1,500
Accounts payable:
Trade creditors	3,382	1,949
Regulatory balancing accounts	1,915	1,797
Other	717	675
Operating lease liabilities	548	553
Interest payable	1,331	4
Disputed claims and customer refunds	238	0
Wildfire-related Claims	26,143	0
Wildfire fund liability	5,200	0
Other	1,579	1,263
Total current liabilities	43,153	7,741
Noncurrent Liabilities
Long-term debt	30,263	0
Regulatory liabilities	9,641	9,270
Pension and other post-retirement benefits	1,836	1,884
Asset retirement obligations	5,961	5,854
Deferred income taxes	1,316	442
Operating lease liabilities	1,573	1,726
Other	4,455	2,626
Total noncurrent liabilities	55,045	21,802
Liabilities Subject to Compromise	0	49,736
Shareholders’ Equity
Preferred stock	258	258
Common stock	1,322	1,322
Additional paid-in capital	8,550	8,550
Reinvested earnings	(4,818)	(4,796)
Accumulated other comprehensive loss	1	1
Total shareholders’ equity	5,313	5,335
TOTAL LIABILITIES AND EQUITY	$ 103,511	$ 84,614

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Allowance for doubtful accounts	$ 81	$ 43
Common stock, par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized (in shares)	3,600,000,000	800,000,000
Common stock, shares outstanding (in shares)	529,793,355	529,236,741
Pacific Gas & Electric Co
Allowance for doubtful accounts	$ 81	$ 43
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

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Cash Flows from Operating Activities
Net Loss	$ (1,594)	$ (2,413)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	1,729	1,593
Allowance for equity funds used during construction	(21)	(45)
Deferred income taxes and tax credits, net	869	(915)
Reorganization items, net	1,558	90
Wildfire fund expense	173	0
Other	142	53
Effect of changes in operating assets and liabilities:
Accounts receivable	(389)	(54)
Wildfire-related insurance receivable	99	35
Inventories	(19)	(41)
Accounts payable	722	159
Wildfire-related claims	619	(14)
Income taxes receivable/payable	0	5
Other current assets and liabilities	529	(15)
Regulatory assets, liabilities, and balancing accounts, net	(1,570)	(34)
Liabilities subject to compromise	413	4,221
Other noncurrent assets and liabilities	31	132
Net cash provided by operating activities	3,291	2,757
Cash Flows from Investing Activities
Capital expenditures	(3,399)	(2,410)
Proceeds from sales and maturities of nuclear decommissioning trust investments	787	517
Purchases of nuclear decommissioning trust investments	(837)	(547)
Other	8	6
Net cash used in investing activities	(3,441)	(2,434)
Cash Flows from Financing Activities
Proceeds from debtor-in-possession credit facility	500	1,850
Repayments of debtor-in-possession credit facility	0	(350)
Debtor-in-possession credit facility debt issuance costs	(3)	(111)
Proceeds from issuance of long-term debt, net of discount and issuance costs	13,510	0
Bridge facility financing fees	(73)	0
Common stock issued	0	85
Other	20	(6)
Net cash provided by financing activities	13,954	1,468
Net change in cash, cash equivalents, and restricted cash	13,804	1,791
Cash, cash equivalents, and restricted cash at January 1	1,577	1,675
Cash, cash equivalents, and restricted cash at June 30	15,381	3,466
Less: Restricted cash and restricted cash equivalents included in other current assets	(14,413)	(7)
Cash and cash equivalents	968	3,459
Cash paid for:
Interest, net of amounts capitalized	0	(21)
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	273	836
Operating lease liabilities arising from obtaining right-of-use assets	13	2,816
Pacific Gas & Electric Co
Cash Flows from Operating Activities
Net Loss	(22)	(2,417)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	1,729	1,593
Allowance for equity funds used during construction	(21)	(45)
Deferred income taxes and tax credits, net	890	(920)
Reorganization items, net	13	91
Wildfire fund expense	173	0
Other	138	34
Effect of changes in operating assets and liabilities:
Accounts receivable	(374)	(64)
Wildfire-related insurance receivable	99	35
Inventories	(19)	(41)
Accounts payable	701	206
Wildfire-related claims	619	(14)
Income taxes receivable/payable	0	4
Other current assets and liabilities	(4)	(8)
Regulatory assets, liabilities, and balancing accounts, net	(1,570)	(34)
Liabilities subject to compromise	401	4,215
Other noncurrent assets and liabilities	47	141
Net cash provided by operating activities	2,800	2,776
Cash Flows from Investing Activities
Capital expenditures	(3,399)	(2,410)
Proceeds from sales and maturities of nuclear decommissioning trust investments	787	517
Purchases of nuclear decommissioning trust investments	(837)	(547)
Other	8	6
Net cash used in investing activities	(3,441)	(2,434)
Cash Flows from Financing Activities
Proceeds from debtor-in-possession credit facility	500	1,850
Repayments of debtor-in-possession credit facility	0	(350)
Debtor-in-possession credit facility debt issuance costs	(3)	(95)
Proceeds from issuance of long-term debt, net of discount and issuance costs	8,850	0
Bridge facility financing fees	(33)	0
Other	20	(6)
Net cash provided by financing activities	9,334	1,399
Net change in cash, cash equivalents, and restricted cash	8,693	1,741
Cash, cash equivalents, and restricted cash at January 1	1,129	1,302
Cash, cash equivalents, and restricted cash at June 30	9,822	3,043
Less: Restricted cash and restricted cash equivalents included in other current assets	(9,076)	(7)
Cash and cash equivalents	746	3,036
Cash paid for:
Interest, net of amounts capitalized	0	(19)
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	273	836
Operating lease liabilities arising from obtaining right-of-use assets	$ 13	$ 2,807

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) $ in Millions	Jun. 30, 2020USD ($)
Unamortized discount, net of premium and debt issuance costs	$ 165
Pacific Gas & Electric Co
Unamortized discount, net of premium and debt issuance costs	$ 75

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY - USD ($) $ in Millions	Total	Common Stock	Reinvested Earnings	Accumulated Other Comprehensive Income (Loss)	Total Shareholders’ Equity	Non- controlling Interest - Preferred Stock of Subsidiary	Pacific Gas & Electric Co	Pacific Gas & Electric CoPreferred Stock	Pacific Gas & Electric CoCommon Stock	Pacific Gas & Electric CoAdditional Paid-in Capital	Pacific Gas & Electric CoReinvested Earnings	Pacific Gas & Electric CoAccumulated Other Comprehensive Income (Loss)	Pacific Gas & Electric CoTotal Shareholders’ Equity
Beginning balance (in shares) at Dec. 31, 2018		520,338,710
Beginning balance at Dec. 31, 2018	$ 12,903	$ 12,910	$ (250)	$ (9)	$ 12,651	$ 252		$ 258	$ 1,322	$ 8,550	$ 2,826	$ (1)	$ 12,955
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	136		136		136						133		133
Other comprehensive loss	0			0	0
Common stock issued, net (in shares)		8,871,568
Common stock issued, net	85	$ 85			85
Stock-based compensation amortization	5	$ 5			5
Ending balance (in shares) at Mar. 31, 2019		529,210,278
Ending balance at Mar. 31, 2019	13,129	$ 13,000	(114)	(9)	12,877	252		258	1,322	8,550	2,959	(1)	13,088
Beginning balance (in shares) at Dec. 31, 2018		520,338,710
Beginning balance at Dec. 31, 2018	12,903	$ 12,910	(250)	(9)	12,651	252		258	1,322	8,550	2,826	(1)	12,955
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(2,413)						$ (2,417)
Ending balance (in shares) at Jun. 30, 2019		529,223,793
Ending balance at Jun. 30, 2019	10,594	$ 13,014	(2,663)	(9)	10,342	252		258	1,322	8,550	409	(1)	10,538
Beginning balance (in shares) at Mar. 31, 2019		529,210,278
Beginning balance at Mar. 31, 2019	13,129	$ 13,000	(114)	(9)	12,877	252		258	1,322	8,550	2,959	(1)	13,088
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(2,549)		(2,549)		(2,549)		$ (2,550)				(2,550)		(2,550)
Other comprehensive loss	0			0	0
Common stock issued, net (in shares)		13,515
Stock-based compensation amortization	14	$ 14			14
Ending balance (in shares) at Jun. 30, 2019		529,223,793
Ending balance at Jun. 30, 2019	$ 10,594	$ 13,014	(2,663)	(9)	10,342	252		258	1,322	8,550	409	(1)	10,538
Beginning balance (in shares) at Dec. 31, 2019	529,236,741	529,236,741					264,374,809
Beginning balance at Dec. 31, 2019	$ 5,388	$ 13,038	(7,892)	(10)	5,136	252		258	1,322	8,550	(4,796)	1	5,335
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	374		374		374						451		451
Other comprehensive loss	0			0	0
Common stock issued, net (in shares)		549,155
Stock-based compensation amortization	(3)	$ (3)			(3)
Ending balance (in shares) at Mar. 31, 2020		529,785,896
Ending balance at Mar. 31, 2020	$ 5,759	$ 13,035	(7,518)	(10)	5,507	252		258	1,322	8,550	(4,345)	1	5,786
Beginning balance (in shares) at Dec. 31, 2019	529,236,741	529,236,741					264,374,809
Beginning balance at Dec. 31, 2019	$ 5,388	$ 13,038	(7,892)	(10)	5,136	252		258	1,322	8,550	(4,796)	1	5,335
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	$ (1,594)						$ (22)
Ending balance (in shares) at Jun. 30, 2020	529,793,355	529,793,355					264,374,809
Ending balance at Jun. 30, 2020	$ 3,801	$ 13,045	(9,486)	(10)	3,549	252		258	1,322	8,550	(4,818)	1	5,313
Beginning balance (in shares) at Mar. 31, 2020		529,785,896
Beginning balance at Mar. 31, 2020	5,759	$ 13,035	(7,518)	(10)	5,507	252		258	1,322	8,550	(4,345)	1	5,786
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(1,968)		(1,968)		(1,968)		$ (473)				(473)		(473)
Other comprehensive loss	0			0	0
Common stock issued, net (in shares)		7,459
Stock-based compensation amortization	$ 10	$ 10			10
Ending balance (in shares) at Jun. 30, 2020	529,793,355	529,793,355					264,374,809
Ending balance at Jun. 30, 2020	$ 3,801	$ 13,045	$ (9,486)	$ (10)	$ 3,549	$ 252		$ 258	$ 1,322	$ 8,550	$ (4,818)	$ 1	$ 5,313

ORGANIZATION AND BASIS OF PRESE

ORGANIZATION AND BASIS OF PRESENTATION	6 Months Ended
	Jun. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
ORGANIZATION AND BASIS OF PRESENTATION	ORGANIZATION AND BASIS OF PRESENTATION Organization and Basis of Presentation PG&E Corporation is a holding company whose primary operating subsidiary is Pacific Gas and Electric Company, a public utility serving northern and central California. The Utility generates revenues mainly through the sale and delivery of electricity and natural gas to customers. The Utility is primarily regulated by the CPUC and the FERC. In addition, the NRC oversees the licensing, construction, operation, and decommissioning of the Utility’s nuclear generation facilities. This quarterly report on Form 10-Q is a combined report of PG&E Corporation and the Utility. PG&E Corporation’s Condensed Consolidated Financial Statements include the accounts of PG&E Corporation, the Utility, and other wholly owned and controlled subsidiaries. The Utility’s Condensed Consolidated Financial Statements include the accounts of the Utility and its wholly owned and controlled subsidiaries. All intercompany transactions have been eliminated in consolidation. The Notes to the Condensed Consolidated Financial Statements apply to both PG&E Corporation and the Utility. PG&E Corporation and the Utility assess financial performance and allocate resources on a consolidated basis (i.e., the companies operate in one segment). The accompanying Condensed Consolidated Financial Statements have been prepared in conformity with GAAP and in accordance with the interim period reporting requirements of Form 10-Q and reflect all adjustments that management believes are necessary for the fair presentation of PG&E Corporation’s and the Utility’s financial condition, results of operations, and cash flows for the periods presented. The information at December 31, 2019 in the Condensed Consolidated Balance Sheets included in this quarterly report was derived from the audited Consolidated Balance Sheets in Item 8 of the 2019 Form 10-K. This quarterly report should be read in conjunction with the 2019 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, insurance receivables, and pension and other post-retirement benefit plan obligations. Management believes that its estimates and assumptions reflected in the Condensed Consolidated Financial Statements are appropriate and reasonable. A change in management’s estimates or assumptions could result in an adjustment that would have a material impact on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows during the period in which such change occurred. Chapter 11 Emergence and Going Concern The accompanying Condensed Consolidated Financial Statements have been prepared on a going concern basis, which contemplates the continuity of operations, the realization of assets and the satisfaction of liabilities in the normal course of business. PG&E Corporation and the Utility suffered material losses as a result of the 2017 Northern California wildfires and the 2018 Camp fire, which contributed to the decision to file for Chapter 11 protection on January 29, 2019. Uncertainty regarding these matters previously raised substantial doubt about PG&E Corporation’s and the Utility’s abilities to continue as going concerns. As a result of PG&E Corporation’s and the Utility’s emergence from Chapter 11 on July 1, 2020 (the “Effective Date”), substantial doubt has been alleviated regarding the Company’s ability to meet its obligations as they become due within one year after the date the financial statements were issued. (For more information regarding the Chapter 11 Cases, see Note 2 below.)

BANKRUPTCY FILING

BANKRUPTCY FILING	6 Months Ended
	Jun. 30, 2019
Reorganizations [Abstract]
BANKRUPTCY FILING	BANKRUPTCY FILING Chapter 11 Proceedings On January 29, 2019, PG&E Corporation and the Utility commenced the Chapter 11 Cases with the Bankruptcy Court. Prior to the Effective Date, PG&E Corporation and the Utility continued to operate their business as debtors-in-possession under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code and orders of the Bankruptcy Court. Under the Bankruptcy Code, third-party actions to collect pre-petition indebtedness owed by PG&E Corporation or the Utility, as well as most litigation pending against PG&E Corporation and the Utility (including the third-party matters described in Note 10 below) as of the Petition Date, were subject to an automatic stay. Except as otherwise set forth in the Plan, the Confirmation Order (as defined below) or another order of the Bankruptcy Court, substantially all pre-petition liabilities were resolved under the Plan. Significant Bankruptcy Court Actions Plan of Reorganization and Restructuring Support Agreements On June 19, 2020, PG&E Corporation and the Utility, certain funds and accounts managed or advised by Abrams Capital Management, LP (“Abrams”), and certain funds and accounts managed or advised by Knighthead Capital Management, LLC (“Knighthead” and, together with Abrams, the “Shareholder Proponents”) filed PG&E Corporation’s and the Utility’s and Shareholder Proponents’ Joint Chapter 11 Plan of Reorganization dated June 19, 2020 with the Bankruptcy Court (the “Plan”). On June 20, 2020, the Bankruptcy Court confirmed the Plan by issuing a confirmation order (the “Confirmation Order”). PG&E Corporation and the Utility emerged from Chapter 11 on July 1, 2020. On September 22, 2019, PG&E Corporation and the Utility entered into a Restructuring Support Agreement with certain holders of insurance subrogation claims (collectively, the “Consenting Subrogation Creditors”) (as amended, the “Subrogation RSA”). As of June 30, 2020, PG&E Corporation and the Utility incurred $52 million in professional fees related to the Subrogation RSA. On December 19, 2019, the Bankruptcy Court entered an order approving the Subrogation RSA. See “Restructuring Support Agreement with Holders of Subrogation Claims” in Note 10 for further information on the Subrogation RSA. On December 6, 2019, PG&E Corporation and the Utility entered into a Restructuring Support Agreement, which was subsequently amended on December 16, 2019 (as amended, the “TCC RSA”), with the TCC, the attorneys and other advisors and agents for holders of claims against PG&E Corporation and the Utility relating to the 2015 Butte fire, the 2017 Northern California wildfires and the 2018 Camp fire (other than the Subrogation Claims and Public Entity Wildfire Claims) (the “Fire Victim Claims”) that are signatories to the TCC RSA (each a “Consenting Fire Claimant Professional”), and the Shareholder Proponents. On December 19, 2019, the Bankruptcy Court entered an order approving the TCC RSA. See “Restructuring Support Agreement with the TCC” in Note 10 for further information on the TCC RSA. On January 22, 2020, PG&E Corporation and the Utility entered into a Restructuring Support Agreement with those holders of senior unsecured debt of the Utility that are identified as “Consenting Noteholders” therein and the Shareholder Proponents (the “Noteholder RSA”). On February 5, 2020, the Bankruptcy Court entered an order approving the Noteholder RSA. See “Restructuring Support Agreement with the Ad Hoc Noteholder Committee” in Note 10 for further information on the Noteholder RSA. Confirmation of the Plan of Reorganization On March 20, 2020, PG&E Corporation and the Utility filed a motion with the Bankruptcy Court (the “Case Resolution Contingency Process Motion”) for entry of an order approving a case resolution contingency process to address the circumstance in which the Plan is not confirmed or fails to become effective in accordance with certain required dates (the “Case Resolution Contingency Process”). The Case Resolution Contingency Process Motion sets forth certain other commitments by PG&E Corporation and the Utility in connection with the confirmation process and implementation of the Plan, including among other things, limitations on the ability of PG&E Corporation to pay dividends; commitments by the Utility with respect to cost recovery of amounts paid in respect of “Fire Claims” under the Plan; the terms of a purchase option in favor of the state of California (which would be exercisable only in limited circumstances); and commitments with respect to the Utility’s utilization of the cash benefits associated with wildfire-related net operating losses. The Bankruptcy Court entered the order approving the Case Resolution Contingency Process Motion on April 9, 2020. On May 28, 2020, the CPUC approved, with conditions and modifications, the Plan pursuant to the requirements of Assembly Bill 1054. Pursuant to the decision, changes to the Utility’s governance structure and enhancements to the CPUC’s oversight have been put in place to facilitate the Utility’s ability to provide safe, reliable and affordable utility service. The CPUC’s final decision was issued on June 1, 2020. The Plan as confirmed by the Confirmation Order provides for certain transactions and the satisfaction and treatment of claims against and interests in PG&E Corporation and the Utility, each in accordance with the terms of the Plan, including the following transactions: • PG&E Corporation and the Utility funded a trust (the “Fire Victim Trust”) for the benefit of all holders of Fire Victim Claims, whose claims were channeled to the Fire Victim Trust on the Effective Date with no recourse to PG&E Corporation and the Utility. In full satisfaction, release, and discharge of all Fire Victim Claims, the Fire Victim Trust was funded with $5.4 billion in cash (with an additional $1.35 billion in cash to be funded on a deferred basis), common stock of the Reorganized Corporation representing 22.19% of the outstanding common stock of the Reorganized Corporation as of the Effective Date (subject to potential adjustments), plus the assignment of certain rights and causes of action; • PG&E Corporation and the Utility funded a trust (the “Subrogation Wildfire Trust”) for the benefit of insurance subrogation claimants in the amount of $11.0 billion in cash. Such amount was initially funded into escrow and later paid to the Subrogation Wildfire Trust. As a result of such funding, all insurance subrogation claims have been satisfied, released and discharged and channeled to the Subrogation Wildfire Trust with no recourse to PG&E Corporation or the Utility; • PG&E Corporation and the Utility paid $1.0 billion in cash to certain local public entities (the “Settling Public Entities”) that entered into plan support agreements with PG&E Corporation and the Utility and established a segregated fund in the amount of $10 million to be used to reimburse the Settling Public Entities for any and all legal fees and costs associated with the defense or resolution of any third party claims against the Settling Public Entities in full satisfaction, release and discharge of such Settling Public Entities’ wildfire related claims; • The Utility Short-Term Senior Notes, the Utility Long-Term Senior Notes and the Utility Funded Debt (except for $100 million of pollution control bonds (Series 2008F and 2010E), which are to be repaid in cash) were refinanced and the Utility Reinstated Senior Notes were reinstated and collateralized on or around the Effective Date through the issuance of a corresponding series of first mortgage bonds of the Utility; • PG&E Corporation paid in full all of its pre-petition funded debt obligations that are allowed in the Chapter 11 Cases; • PG&E Corporation and the Utility repaid all borrowings under the DIP Facilities and will pay all other allowed administrative expense claims in accordance with the Plan; • Holders of Allowed Priority Tax Claims will receive in the third quarter of 2020, at the option of PG&E Corporation and the Utility, (i) Cash in an amount equal to such Allowed Priority Tax Claims on the Effective Date or as soon as reasonably practicable thereafter, or (ii) Cash in equal, semi-annual installments over a period not exceeding five years from and after the Petition Date; • Holders of Allowed Other Secured Claims will, at the option of PG&E Corporation and the Utility, (i) retain their Other Secured Claims and the Collateral securing such Claims; (ii) receive Cash in an amount equal to such Allowed Secured Claims; or (iii) receive treatment of such Allowed Other Secured Claims in any other manner that is necessary to satisfy the requirements of section 1124 of the Bankruptcy Code; • Holders of Allowed Priority Non-Tax Claims will, at the option of PG&E Corporation and the Utility, receive (i) Cash in an amount equal to such Allowed Priority Non-Tax Claims, or (ii) such other treatment consistent with the provisions of section 1129(a)(9) of the Bankruptcy Code; • PG&E Corporation and the Utility will pay in full all pre-petition General Unsecured Claims that are allowed in the Chapter 11 Cases; and • PG&E Corporation and the Utility will pay all Allowed Subordinated Debt Claims in full and provide to each holder of an Allowed HoldCo Rescission or Damage Claim a number of shares of New HoldCo Common Stock based on a formula as specified in the Plan that varies depending on when the claimant purchased the affected shares of common stock. In addition, the Plan also provides for the following in connection with or following the implementation of the Plan: • Holders of claims related to the 2016 Ghost Ship fire will be entitled to pursue their claims against PG&E Corporation and the Utility, with any recovery being limited to amounts available under PG&E Corporation’s and the Utility’s insurance policies for the 2016 year; • Holders of certain claims may be able to pursue their claims against PG&E Corporation and the Utility, such as administrative expense claims that have not been satisfied or come due by the Effective Date, claims arising from wildfires occurring after the Petition Date that have not been satisfied by the Effective Date (including the Kincade Fire), and claims relating to certain FERC refund proceedings, workers’ compensation benefits and certain environmental claims; • PG&E Corporation or the Utility, as applicable, assumed all of their respective power purchase agreements and community choice aggregation servicing agreements; and • PG&E Corporation or the Utility, as applicable, assumed all of their respective pension obligations, other employee obligations, and collective bargaining agreements with labor. The Confirmation Order contains a Channeling Injunction that is also in the Plan that provides, among other things, that the sole source of recovery for holders of Subrogation Wildfire Claims will be from the Subrogation Wildfire Trust and the sole source of recovery for holders of Fire Victim Claims will be from the Fire Victim Trust. The holders of such Claims will have no recourse to or Claims whatsoever against PG&E Corporation and the Utility or their assets and properties. The Plan as confirmed by the Confirmation Order provides for certain financing transactions as follows: • one or more equity offerings of up to $9.0 billion of gross proceeds in cash through the issuance of common stock and/or other equity and/or equity-linked securities pursuant to one or more offerings and/or private placements; • the issuance of $4.75 billion of new PG&E Corporation debt; • the reinstatement of $9.575 billion of pre-petition debt of the Utility; and • the issuance of $23.775 billion of new Utility debt, consisting of (i) $6.2 billion of New Utility Long-Term Bonds to be issued to holders of certain pre-petition senior notes of the Utility pursuant to the Plan, (ii) $1.75 billion of New Utility Short-Term Bonds to be issued to holders of certain pre-petition senior notes of the Utility pursuant to the Plan, (iii) $3.9 billion of New Utility Funded Debt Exchange Bonds to be issued to holders of certain pre-petition indebtedness of the Utility pursuant to the Plan and (iv) $11.925 billion of new debt securities or bank debt of the Utility to be issued to third parties for cash on or prior to the Effective Date (of which $6.0 billion is expected to be repaid with the proceeds of a new securitization transaction after the Effective Date) (see Note 5 below for a description of the debt transactions that occurred on or before the Effective Date). As described below, the foregoing financing transactions occurred on or around the Effective Date. Restructuring Support Agreement with the Ad Hoc Noteholder Committee On January 22, 2020, PG&E Corporation and the Utility entered into the Noteholder RSA with those holders of senior unsecured debt of the Utility that are identified as “Consenting Noteholders” therein and the Shareholder Proponents. The Noteholder RSA provides for, among other things, (i) the refinancing of the Utility’s senior unsecured debt in satisfaction of all claims arising out of the Utility Short-Term Senior Notes, the Utility Long-Term Senior Notes and the Utility Funded Debt, and (ii) the reinstatement of the Utility Reinstated Senior Notes (together with the Utility Short-Term Senior Notes and Utility Long-Term Senior Notes, the “Utility Senior Note Claims”), in each case pursuant to the Plan and upon the terms and conditions set forth in the Noteholder RSA. Under the Noteholder RSA, PG&E Corporation and the Utility also agreed to reimburse the holders of Utility Long-Term Senior Notes for debt placement fees and the members of the Ad Hoc Noteholder Committee for professional fees of up to $106 million upon the terms and conditions set forth in the Noteholder RSA. On July 1, 2020, the Utility recorded $102 million in fees as additional debt discount on the Utility’s refinanced debt. The Noteholder RSA provides for the following treatment of Utility Senior Note Claims and Utility Funded Debt which treatment was incorporated into the Plan: • Utility Short-Term Senior Notes: Utility notes outstanding at June 30, 2020 maturing through 2022 in an aggregate principal amount of $1.75 billion (the “Utility Short-Term Senior Notes”) received new Utility first mortgage bonds in the following aggregate principal amounts: $875 million of new Utility 3.45% first mortgage bonds due 2025 and $875 million of new Utility 3.75% first mortgage bonds due 2028 (together, the “New Utility Short-Term Bonds”). The New Utility Short-Term Bonds otherwise have substantially similar terms and conditions as the Utility’s 6.05% Senior Notes due March 1, 2034. Additionally, holders of claims arising out of the Utility Short-Term Senior Notes received cash in an amount equal to the sum of (1) the amount of pre-petition interest outstanding on the Utility Short-Term Senior Notes calculated using the applicable non-default contract rate and (2) interest calculated using the Federal Judgment Rate on the sum of (A) the applicable principal amount of the Utility Short-Term Senior Notes and (B) the amount in clause (1) for the period commencing on the day after the Petition Date and ending on the Effective Date. • Utility Long-Term Senior Notes: All long-term Utility notes bearing an interest rate greater than 5.00%, of which there is an aggregate principal amount outstanding of $6.2 billion (the “Utility Long-Term Senior Notes”), received new Utility first mortgage bonds in the following aggregate principal amounts: $3.1 billion of new Utility 4.55% first mortgage bonds due 2030 and $3.1 billion of new Utility 4.95% first mortgage bonds due 2050 (together, the “New Utility Long-Term Bonds”). The New Utility Long-Term Bonds otherwise have substantially similar terms and conditions as the Utility’s 3.95% Senior Notes due December 1, 2047. Additionally, holders of claims arising out of the Utility Long-Term Senior Notes received cash in an amount equal to the sum of (1) the amount of pre-petition interest outstanding on the Utility Long-Term Senior Notes calculated using the applicable non-default contract rate and (2) interest calculated using the federal judgment rate on the sum of (A) the applicable principal amount of the Utility Long-Term Senior Notes and (B) the amount in clause (1) for the period commencing on the Petition Date and ending on the Effective Date. • Utility Reinstated Senior Notes: The remaining outstanding $9.575 billion aggregate principal amount of Utility notes (the “Utility Reinstated Senior Notes”) were reinstated on their contractual terms, including being secured equally and ratably with the New Utility Short-Term Notes and the New Utility Long-Term Notes for so long as any outstanding Utility debt is secured, subject to certain exceptions. • Utility Funded Debt: Holders of the Utility’s pre-petition credit facilities and Pollution Control bonds (collectively, the “Utility Funded Debt”) received new Utility secured notes in the following aggregate principal amounts: $1.95 billion in new Utility 3.15% first mortgage bonds due 2026 that will otherwise have the same terms and conditions as the Utility’s 6.05% Senior Notes due March 1, 2034, and $1.95 billion in new Utility 4.50% first mortgage bonds due 2040 that will otherwise have the same terms and conditions as the Utility’s 3.95% Senior Notes due December 1, 2047 (the “New Utility Funded Debt Exchange Bonds”). Additionally, holders of claims arising out of the Utility Funded Debt received cash in an amount equal to the sum of (1) the amount of pre-petition interest outstanding on the Utility Funded Debt calculated using the applicable non-default contract rate, (2) fees and charges and other obligations owed as of the Petition Date in respect of the Utility Funded Debt, (3) reasonable attorney’s fees and expenses of counsel, subject a maximum of $6 million and (4) interest calculated using the federal judgment rate on the sum of (A) the applicable principal amount of the Utility Funded Debt and (B) the amount in clauses (1) and (2) for the period commencing on the Petition Date and ending on the Effective Date. As described below in Note 12, on July 27, 2020, Elliott Management Corporation, a Consenting Noteholder, filed a motion with the Bankruptcy Court asserting an approximately $250 million administrative claim against PG&E Corporation and the Utility, alleging that PG&E Corporation and the Utility breached the Noteholder RSA by failing to use their best efforts to cause Backstop Parties to transfer up to $2.0 billion of Backstop Commitments to certain of the Consenting Noteholders. Objections to the motion are due on August 11, 2020, and a hearing on the motion is scheduled for August 25, 2020. PG&E Corporation and the Utility are unable to predict the timing and outcome of this proceeding. Debt Commitment Letters On October 11, 2019, PG&E Corporation and the Utility entered into debt commitment letters, which were subsequently amended on November 18, 2019, December 20, 2019, January 30, 2020, and February 14, 2020 (as amended, the “Debt Commitment Letters”) with JPMorgan Chase Bank, N.A., Bank of America, N.A., BofA Securities, Inc., Barclays Bank PLC, Citigroup Global Markets Inc., Goldman Sachs Bank USA, Goldman Sachs Lending Partners LLC and the other lenders that may become parties to the Debt Commitment Letters as additional “Commitment Parties” as provided therein (the foregoing parties, collectively, the “Commitment Parties”), pursuant to which the Commitment Parties committed to provide $10.825 billion in bridge financing in the form of (a) a $5.825 billion senior secured bridge loan facility (the “OpCo Facility”) with the Utility or any domestic entity formed to hold all of the assets of the Utility upon emergence from bankruptcy (the Utility or any such entity, the “OpCo Borrower”) as borrower thereunder and (b) a $5.0 billion senior unsecured bridge loan facility (together with the OpCo Facility, the “Facilities”) with PG&E Corporation or any domestic entity formed to hold all of the assets of PG&E Corporation upon emergence from bankruptcy (PG&E Corporation or any such entity, the “HoldCo Borrower”) as borrower thereunder, subject to the terms and conditions set forth therein. On March 16, 2020, the Bankruptcy Court approved the Debt Commitment Letters as amended through February 14, 2020. PG&E Corporation and the Utility recorded facility fees of $4 million and $2 million, respectively, during the three months ended June 30, 2020 and $40 million and $33 million respectively, during the six months ended June 30, 2020, reflected in Reorganization items, net on the Condensed Consolidated Statements of Income. Of the $33 million in cash paid for the Utility’s facility fees, during the six months ended June 30, 2020, the Utility recorded $18 million to a regulatory asset for fees that are deemed probable of recovery. In lieu of entering into the Facilities contemplated by the Debt Commitment Letters, PG&E Corporation and the Utility obtained permanent exit financing in the form of bank facilities and debt securities and terminated the Debt Commitment Letters of the Utility on June 19, 2020 and PG&E Corporation on June 23, 2020. Equity Financing In connection with its emergence from Chapter 11 in July 2020, PG&E raised an aggregate of $9.0 billion of gross proceeds through the issuance of common stock and other equity-linked instruments. For more information, see Note 6 below. Equity Backstop Commitments and Forward Stock Purchase Agreements As of March 6, 2020, PG&E Corporation entered into Chapter 11 Plan Backstop Commitment Letters (collectively, as amended by the Consent Agreements (as defined below), the “Backstop Commitment Letters”) with investors (collectively, the “Backstop Parties”), pursuant to which the Backstop Parties severally agreed to fund up to $12.0 billion of proceeds to finance the Plan through the purchase of PG&E Corporation common stock, subject to the terms and conditions set forth in such Backstop Commitment Letters (the “Backstop Commitments”). As a result of PG&E Corporation emerging from Chapter 11 on July 1, 2020, the Backstop Commitments were not utilized and terminated in accordance with their terms. The commitment premium for the Backstop Commitments was paid in shares of PG&E Corporation’s common stock (with each Backstop Party receiving its pro rata share of 119 million shares of PG&E Corporation’s common stock based on the proportion of the amount of such Backstop Party’s Backstop Commitment to $12.0 billion). PG&E Corporation issued the commitment premium shares to the Backstop Parties on July 1, 2020 in connection with emerging from Chapter 11. As of June 30, 2020, PG&E Corporation recorded approximately $1.1 billion of expense related to the Backstop Commitment premium in Reorganization items, net. This amount was primarily based on PG&E Corporation’s closing stock price on June 30, 2020 of $8.87 per share. On the Effective Date, PG&E Corporation’s closing price was $9.03 per share and as a result, PG&E Corporation will record an additional $27 million expense in the third quarter of 2020. Under the Backstop Commitment Letters, PG&E Corporation and the Utility have also agreed to reimburse the Backstop Parties for reasonable professional fees and expenses of up to $34 million in the aggregate for the legal advisors and $19 million in the aggregate for the financial advisor, upon the terms and conditions set forth in the Backstop Commitment Letters. As of June 30, 2020, PG&E Corporation recorded $49 million in professional fees and related expenses to the Backstop parties in Reorganization items, net. In connection with PG&E Corporation’s underwritten offerings of up to $5.75 billion of equity securities to finance the transactions contemplated by the Plan (the “Offerings”), up to $523 million (the “Option Amount”) was issuable pursuant to customary options granted to the underwriters thereof to purchase additional securities (the “Option Securities”). On June 19, 2020, PG&E Corporation entered into prepaid forward contracts (the “Forward Stock Purchase Agreements”) with the Backstop Parties. Each Forward Stock Purchase Agreement provides that, subject to certain conditions, the Backstop Party will purchase on the Effective Date, and receive on the Settlement Date (as defined in each Forward Stock Purchase Agreement) an amount of common stock of PG&E Corporation equal to its pro rata share of the value of the Option Securities which is approximately $523 million (such amount, each Backstop Party’s “Greenshoe Backstop Purchase Amount”), at a price per share equal to the lesser of (i) the lowest per share price of common stock sold on an underwritten basis to the public in an offering of common stock of PG&E Corporation, as disclosed on the cover page of the prospectus or prospectus supplement, and (ii) the price per share payable by the investors party to the Investment Agreement dated as of June 7, 2020 (such lesser price, the “Settlement Price”). The Settlement Price is $9.50 per share. Each Forward Stock Purchase Agreement expires on the later of (x) 30 days from June 25, 2020 and (y) the latest settlement date for the sale of Option Securities to the underwriters. On June 25, 2020, the Backstop Parties funded the Greenshoe Backstop Purchase Amount to PG&E Corporation in the amount of $523 million which is recorded in Other current liabilities on the Condensed Consolidated Financial Statements. As of June 30, 2020, no portion of the Greenshoe Backstop Purchase Amount had been settled or redeemed. PG&E Corporation applied the proceeds of such funding to distributions under the Plan on the Effective Date . On August 3, 2020, PG&E Corporation will redeem $120.5 million of the Forward Stock Purchase Agreements payable in cash as a result of the exercise by the underwriters of their option to purchase Equity Units pursuant to the Equity Units Underwriting Agreement. On August 3, 2020, PG&E Corporation will deliver 42.3 million shares of PG&E Corporation common stock to the Backstop Parties to settle the portion of the Forward Stock Purchase Agreements that will not be redeemed. Additionally, each Forward Stock Purchase Agreement provides that, subject to the consummation by PG&E Corporation of the Offerings, PG&E Corporation will issue to each Backstop Party its pro rata share of 50 million shares of common stock (such shares, each Backstop Party’s “Additional Backstop Premium Shares”). The Additional Backstop Premium Shares were issued to Backstop Parties on the Effective Date. As of June 30, 2020, PG&E Corporation recorded $444 million of expense related to the Additional Backstop Premium Shares in Reorganization items, net. This amount was based primarily on PG&E Corporation’s closing stock price on June 30, 2020 of $8.87 per share. On the Effective Date, PG&E Corporation’s closing stock price was $9.03 per share and as a result, PG&E Corporation will record an additional $8 million expense in the third quarter of 2020. Financial Reporting in Reorganization Effective on the Petition Date and up to June 30, 2020, PG&E Corporation and the Utility applied accounting standards applicable to reorganizations, which are applicable to companies under Chapter 11 bankruptcy protection. These accounting standards require the financial statements for periods subsequent to the Petition Date to distinguish transactions and events that are directly associated with the reorganization from the ongoing operations of the business. Expenses, realized gains and losses, and provisions for losses that was directly associated with reorganization proceedings must have been reported separately as reorganization items, net in the Condensed Consolidated Statements of Income. In addition, the balance sheet must have distinguished pre-petition LSTC of PG&E Corporation and the Utility from pre-petition liabilities that were not subject to compromise, post-petition liabilities, and liabilities of the subsidiaries of PG&E Corporation that were not debtors in the Chapter 11 Cases in the Condensed Consolidated Balance Sheets. LSTC are pre-petition obligations that were not fully secured and had at least a possibility of not being repaid at the full claim amount. Where there was uncertainty about whether a secured claim will be paid or impaired pursuant to the Chapter 11 Cases, PG&E Corporation and the Utility have classified the entire amount of the claim as LSTC. Furthermore, the realization of assets and the satisfaction of liabilities are subject to uncertainty. Pursuant to the Plan and Confirmation Order, actions to enforce or otherwise effect the payment of certain claims against PG&E Corporation and the Utility in existence before the Petition Date are subject to an injunction and will be satisfied pursuant to the Plan and the Chapter 11 claims reconciliation process. These claims were reflected as LSTC in the Condensed Consolidated Balance Sheets at December 31, 2019. Additional claims may arise after the Petition Date resulting from the rejection of executory contracts, including leases, and from the determination by the Bankruptcy Court (or agreement by parties-in-interest) of allowed claims for contingencies and other disputed amounts. PG&E Corporation’s Condensed Consolidated Financial Statements are presented on a consolidated basis and include the accounts of PG&E Corporation and the Utility and other subsidiaries of PG&E Corporation and the Utility that individually and in aggregate are immaterial. Such other subsidiaries did not file for bankruptcy. The Utility’s Condensed Consolidated Financial Statements are presented on a consolidated basis and include the accounts of the Utility and other subsidiaries of the Utility that individually and in aggregate are immaterial. Such other subsidiaries did not file for bankruptcy. Upon emergence from Chapter 11 on July 1, 2020, PG&E Corporation and the Utility were not required to apply fresh start accounting based on the provisions of ASC 852 since the entity’s reorganization value immediately before the date of confirmation is more than the total of all its post-petition liabilities and allowed claims. Liabilities Subject to Compromise As a result of the commencement of the Chapter 11 Cases, the payment of pre-petition liabilities was subject to compromise or other treatment pursuant to the Plan. Generally, actions to enforce or otherwise effect payment of pre-petition liabilities were subject to an injunction and will be satisfied pursuant to the Plan and the Chapter 11 claims reconciliation process. Although payment of pre-petition claims outside of the Plan generally is not permitted, the Bankruptcy Court granted PG&E Corporation and the Utility authority to pay certain pre-petition claims in designated categories and subject to certain terms and conditions. This relief generally was designed to preserve the value of PG&E Corporation’s and the Utility’s business and assets. Prior to June 30, 2020, pre-petition liabilities that were subject to compromise were required to be reported at the amounts expected to be allowed. Therefore, liabilities subject to compromise as of December 31, 2019 in the table below reflected management’s estimates of amounts expected to be allowed in the Chapter 11 Cases, based upon, among other things, the status of negotiations with creditors. As of June 30, 2020, such amounts have been reclassified to current or non-current liabilities in the Condensed Consolidated Balance Sheets, based upon management’s judgment as to the timing for settlement of such liabilities. Liabilities subject to compromise as of December 31, 2019 which were settled or reclassified during the six months ended June 30, 2020 consist of the following: (in millions) Utility PG&E Corporation (1) December 31, 2019 Change in Estimated Allowed Claim 2020 (2) Cash Reclassified (3) Utility PG&E Corporation (1) June 30, 2020 Financing debt $ 22,450 $ 666 $ 23,116 $ 351 $ — $ (23,467) $ — $ — $ — Wildfire-related claims 25,548 — 25,548 18 (23) (25,543) — — — Trade creditors (4) 1,183 5 1,188 6 (14) (1,180) — — — Non-qualified benefit plan 20 137 157 — — (157) — — — 2001 bankruptcy disputed claims 234 — 234 4 — (238) — — — Customer deposits & advances 71 — 71 12 — (83) — — — Other 230 2 232 59 — (291) — — — Total Liabilities Subject to Compromise $ 49,736 $ 810 $ 50,546 $ 450 $ (37) $ (50,959) $ — $ — $ — (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) Change in estimated allowed cla

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES For a summary of the significant accounting policies used by PG&E Corporation and the Utility, see Note 2 of the Condensed Consolidated Financial Statements above for bankruptcy-related policies and Note 3 of the Notes to the Consolidated Financial Statements in Item 8 of the 2019 Form 10-K. 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. 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 has a controlling interest or was the primary beneficiary of any of these VIEs at June 30, 2020, the Utility assessed whether it absorbs any of the VIE’s expected losses or receives any portion of the VIE’s expected residual returns under the terms of the power purchase agreement, analyzed the variability in the VIE’s gross margin, and considered whether it had any decision-making rights associated with the activities that are most significant to the VIE’s performance, such as dispatch rights and operating and maintenance activities. The Utility’s financial obligation is limited to the amount the Utility pays for delivered electricity and capacity. The Utility did not have any decision-making rights associated with any of the activities that are most significant to the economic performance of any of these VIEs. Since the Utility was not the primary beneficiary of any of these VIEs at June 30, 2020, it did not consolidate any of them. Pension and Other Post-Retirement Benefits PG&E Corporation and the Utility sponsor a non-contributory defined benefit pension plan and cash balance plan. Both plans are included in “Pension Benefits” below. Post-retirement medical and life insurance plans are included in “Other Benefits” below. The net periodic benefit costs reflected in PG&E Corporation’s Condensed Consolidated Financial Statements for the three and six months ended June 30, 2020 and 2019 were as follows: Pension Benefits Other Benefits Three Months Ended June 30, (in millions) 2020 2019 2020 2019 Service cost for benefits earned (1) $ 132 $ 111 $ 16 $ 14 Interest cost 179 190 15 19 Expected return on plan assets (261) (226) (35) (30) Amortization of prior service cost (2) (2) 4 3 Amortization of net actuarial loss 1 — (5) (1) Net periodic benefit cost 49 73 (5) 5 Regulatory account transfer (2) 34 10 — — Total $ 83 $ 83 $ (5) $ 5 (1) A portion of service costs are capitalized pursuant to GAAP. (2) The Utility recorded these amounts to a regulatory account since they are probable of recovery from, or refund to, customers in future rates. Pension Benefits Other Benefits Six Months Ended June 30, (in millions) 2020 2019 2020 2019 Service cost for benefits earned (1) $ 264 $ 222 $ 31 $ 28 Interest cost 357 379 31 38 Expected return on plan assets (522) (453) (69) (61) Amortization of prior service cost (3) (3) 7 7 Amortization of net actuarial loss 2 1 (10) (2) Net periodic benefit cost 98 146 (10) 10 Regulatory account transfer (2) 68 21 — — Total $ 166 $ 167 $ (10) $ 10 (1) A portion of service costs are capitalized pursuant to GAAP. (2) The Utility recorded these amounts to a regulatory account since they are probable of recovery from, or refund to, customers in future rates. Non-service costs are reflected in Other income, net on the Condensed Consolidated Statements of Income. Service costs are reflected in Operating and maintenance on the Condensed Consolidated Statements of Income. There was no material difference between PG&E Corporation and the Utility for the information disclosed above. Pursuant to the Plan and Confirmation Order, all existing pension and other benefit plans were deemed assumed by PG&E Corporation and the Utility. Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (Loss) The changes, net of income tax, in PG&E Corporation’s accumulated other comprehensive income (loss) consisted of the following: Pension Other Total (in millions, net of income tax) Three Months Ended June 30, 2020 Beginning balance $ (22) $ 17 $ (5) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1 and $1, respectively) (1) 3 2 Amortization of net actuarial loss (net of taxes of $1 and $1, respectively) — (4) (4) Regulatory account transfer (net of taxes of $0 and $0, respectively) 1 1 2 Net current period other comprehensive gain (loss) — — — Ending balance $ (22) $ 17 $ (5) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.) Pension Benefits Other Total (in millions, net of income tax) Three Months Ended June 30, 2019 Beginning balance $ (21) $ 17 $ (4) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1 and $1, respectively) (1) 2 1 Amortization of net actuarial loss (net of taxes of $0, and $1, respectively) — — — Regulatory account transfer (net of taxes of $1 and $0, respectively) 1 (2) (1) Net current period other comprehensive gain (loss) — — — Ending balance $ (21) $ 17 $ (4) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.) Pension Benefits Other Benefits Total (in millions, net of income tax) Six Months Ended June 30, 2020 Beginning balance $ (22) $ 17 $ (5) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1 and $2, respectively) (2) 5 3 Amortization of net actuarial loss (net of taxes of $1 and $3, respectively) 1 (7) (6) Regulatory account transfer (net of taxes of $0 and $1, respectively) 1 2 3 Net current period other comprehensive gain (loss) — — — Ending balance $ (22) $ 17 $ (5) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.) Pension Benefits Other Benefits Total (in millions, net of income tax) Six Months Ended June 30, 2019 Beginning balance $ (21) $ 17 $ (4) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1 and $2, respectively) (2) 5 3 Amortization of net actuarial loss (net of taxes of $0 and $1, respectively) 1 (1) — Regulatory account transfer (net of taxes of $1 and $1, respectively) 1 (4) (3) Net current period other comprehensive gain (loss) — — — Ending balance $ (21) $ 17 $ (4) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.) There was no material difference between PG&E Corporation and the Utility for the information disclosed above. Revenue Recognition Revenue from Contracts with Customers The Utility recognizes revenues when electricity and natural gas services are delivered. The Utility records unbilled revenues for the estimated amount of energy delivered to customers but not yet billed at the end of the period. Unbilled revenues are included in accounts receivable on the Condensed Consolidated Balance Sheets. Rates charged to customers are based on CPUC and FERC authorized revenue requirements. Revenues can vary significantly from period to period because of seasonality, weather, and customer usage patterns. Regulatory Balancing Account Revenue The CPUC authorizes most of the Utility’s revenues in the Utility’s GRC and GT&S rate cases, which generally occur every three or four years. The Utility’s ability to recover revenue requirements authorized by the CPUC in these rate cases is independent, or “decoupled,” from the volume of the Utility’s sales of electricity and natural gas services. The Utility recognizes revenues that have been authorized for rate recovery, are objectively determinable and probable of recovery, and are expected to be collected within 24 months. Generally, electric and natural gas operating revenue is recognized ratably over the year. The Utility records a balancing account asset or liability for differences between customer billings and authorized revenue requirements that are probable of recovery or refund. The CPUC also has authorized the Utility to collect additional revenue requirements to recover costs that the Utility has been authorized to pass on to customers, including costs to purchase electricity and natural gas, and to fund public purpose, demand response, and customer energy efficiency programs. In general, the revenue recognition criteria for pass-through costs billed to customers are met at the time the costs are incurred. The Utility records a regulatory balancing account asset or liability for differences between incurred costs and customer billings or authorized revenue meant to recover those costs, to the extent that these differences are probable of recovery or refund. As a result, these differences have no impact on net income. The following table presents the Utility’s revenues disaggregated by type of customer: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2020 2019 2020 2019 Electric Revenue from contracts with customers Residential $ 987 $ 994 $ 2,230 $ 2,282 Commercial 1,075 1,135 2,082 2,088 Industrial 342 326 682 619 Agricultural 368 261 491 347 Public street and highway lighting 17 16 34 33 Other (1) 269 — 203 (309) Total revenue from contracts with customers - electric 3,058 2,732 5,722 5,060 Regulatory balancing accounts (2) 377 214 753 678 Total electric operating revenue $ 3,435 $ 2,946 $ 6,475 $ 5,738 Natural gas Revenue from contracts with customers Residential $ 426 $ 343 $ 1,492 $ 1,515 Commercial 110 129 344 369 Transportation service only 296 304 643 686 Other (1) (159) (129) (180) (205) Total revenue from contracts with customers - gas 673 647 2,299 2,365 Regulatory balancing accounts (2) 425 350 65 (149) Total natural gas operating revenue 1,098 997 2,364 2,216 Total operating revenues $ 4,533 $ 3,943 $ 8,839 $ 7,954 (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. Initial and annual contributions to the Wildfire Fund established pursuant to AB 1054 On the Effective Date, PG&E Corporation and the Utility contributed, in accordance with AB 1054, an initial contribution of approximately $4.8 billion and first annual contribution of approximately $193 million to the Wildfire Fund to secure participation of the Utility therein. PG&E Corporation and the Utility will account for the contributions to the Wildfire Fund similarly to prepaid insurance with expense being allocated to periods ratably based on an estimated period of coverage. At June 30, 2020, PG&E Corporation and the Utility satisfied the eligibility and other requirements set forth in AB 1054 and as a result, upon payment of the initial contribution on the Effective Date, the Wildfire Fund is available to pay for eligible claims arising as of the effective date of AB 1054, subject to a limit of 40% of the amount of such claims arising as of the effective date of AB 1054 and the Utility’s emergence from Chapter 11, additionally limited to the portion of such claims that exceeds the greater of (i) $1.0 billion in the aggregate in any calendar year and (ii) the amount of insurance coverage required to be in place for the electric utility company pursuant to Section 3293 of the Public Utilities Code, added by AB 1054. Therefore, PG&E Corporation and the Utility have recorded a current liability of $5.2 billion in “Wildfire fund liability” and $1.5 billion in Other noncurrent liabilities for the present value of unpaid contribution amounts, as well as $6.5 billion in assets for its commitment to make contributions, reduced by amortization, of which $6.0 billion are non-current, called “Wildfire fund asset” in the Condensed Consolidated Balance Sheets. On June 30, 2020, the Utility recorded amortization expense of $173 million related to the coverage received from the effective date of AB 1054 to June 30, 2020. The amortization of the asset, accretion of the liability, and if applicable, impairment of the asset is reflected in “Wildfire fund expense” in the Condensed Consolidated Statements of Income. Contributions are discounted to the present value using the 10-year US treasury rate at the date PG&E Corporation and the Utility satisfied all the eligibility requirements to participate in the Wildfire Fund. A useful life of 15 years is being used to amortize the Wildfire Fund asset. AB 1054 did not specify a period of coverage, therefore, this accounting treatment is subject to significant accounting judgments and estimates. In estimating the period of coverage, PG&E Corporation and the Utility used a Monte Carlo simulation based on twelve years of historical data from wildfires caused by electrical equipment to estimate expected loss. The assumptions create a high degree of uncertainty related to the estimated useful life of the Wildfire Fund. The most significant assumption is the number and severity of catastrophic fires that could occur in California within the participating electric utilities’ service territories during the term of the Wildfire Fund. PG&E Corporation and the Utility utilize historical, publicly available fire-loss data as a starting point; however, future fire-loss can be difficult to estimate due to uncertainties around the impacts of climate change, land use changes, and mitigation efforts by the California electric utility companies. Other assumptions include the estimated cost of wildfires caused by other electric utilities, the amount at which wildfire claims would be settled, the likely adjudication of the CPUC in cases of electric utility-caused wildfires, the level of future insurance coverage held by the electric utilities, the FERC-allocable portion of loss recovery, and the future transmission and distribution equity rate base growth of other electric utilities. Significant changes in any of these estimates could materially impact the amortization period. PG&E Corporation and the Utility will evaluate all assumptions quarterly, or upon claims being made from the Wildfire Fund for catastrophic wildfires, and the expected life of the Wildfire Fund will be adjusted as required. PG&E Corporation and the Utility will assess the Wildfire Fund asset for impairment in the event that a participating utility's electrical equipment is found to be the substantial cause of a catastrophic wildfire. Timing of any such impairment could lag as the emergence of sufficient cause and claims information can take many quarters and could be limited to public disclosure of the participating electric utility, if ignition were to occur outside the Utility’s service territory. At June 30, 2020, there were no such known events requiring a reduction of the Wildfire Fund asset. Recently Adopted Accounting Standards Intangibles—Goodwill and Other In August 2018, the FASB issued ASU No. 2018-15, Intangibles – Goodwill and Other – Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement that is a Service Contract. PG&E Corporation and the Utility adopted the ASU on January 1, 2020. The adoption of this ASU did not have a material impact on the Condensed Consolidated Financial Statements and related disclosures. Financial Instruments—Credit Losses In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments – Credit Losses (Topic 326), which provides a model, known as the current expected credit loss model, to estimate the expected lifetime credit loss on financial assets, including trade and other receivables, rather than incurred losses over the remaining life of most financial assets measured at amortized cost. The guidance also requires use of an allowance to record estimated credit losses on available-for-sale debt securities. PG&E Corporation and the Utility adopted the ASU on January 1, 2020. PG&E Corporation and the Utility have three categories of financial assets in scope, each with their own associated credit risks. In applying the new guidance, PG&E Corporation and the Utility have incorporated forward-looking data in its estimate of credit loss as follows. Trade receivables are represented by customer accounts receivable and have credit exposure risk related to California unemployment rates. 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. Lastly, available-for-sale debt securities requires each company to determine if a decline in fair value is below amortized costs basis, or, impaired. Furthermore, if an impairment exists on available-for-sale debt securities, PG&E Corporation and the Utility will examine if there is an intent to sell, if it is more likely than not a requirement to sell prior to recovery, and if a portion of the unrealized loss is a result of credit loss. There was no material impact to PG&E Corporation or the Utility’s Condensed Consolidated Financial Statements resulting from the adoption of this ASU. During the three months ended June 30, 2020, expected credit losses of $44 million were recorded in Operating and maintenance expense on the Condensed Consolidated Statements of Income. Reference Rate Reform In March 2020, the FASB issued ASU No. 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting , which provides optional guidance for a limited period of time to ease the potential burden in accounting for (or recognizing the effects of) reference rate reform on financial reporting. PG&E Corporation and the Utility adopted this ASU on April 1, 2020 and elected the optional amendments for contract modifications prospectively. There was no material impact to PG&E Corporation or the Utility’s Condensed Consolidated Financial Statements resulting from the adoption of this ASU. Accounting Standards Issued But Not Yet Adopted Defined Benefit Plans In August 2018, the FASB issued ASU No. 2018-14, Fair Value Measurement (Subtopic 715-20): Disclosure Framework-Changes to the Disclosure Requirements for Defined Benefit Plans , which amends the existing guidance relating to the disclosure requirements for Defined Benefit Plans. PG&E Corporation and the Utility plan to adopt this guidance in the fourth quarter of 2020. PG&E Corporation and the Utility are currently evaluating the impact the guidance will have on their Condensed Consolidated Financial Statements and related disclosures. Income Taxes In December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes , which amends the existing guidance to reduce complexity relating to Income Tax disclosures. PG&E Corporation and the Utility plan to adopt this guidance in the first quarter of 2021. PG&E Corporation and the Utility does not anticipate the guidance will have a material impact on their Condensed Consolidated Financial Statements and related disclosures.

REGULATORY ASSETS, LIABILITIES,

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	6 Months Ended
	Jun. 30, 2020
Regulated Operations [Abstract]
REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS Regulatory Assets and Liabilities Regulatory Assets Long-term regulatory assets are comprised of the following: Balance at (in millions) June 30, 2020 December 31, 2019 Pension benefits (1) $ 1,757 $ 1,823 Environmental compliance costs 1,082 1,062 Utility retained generation (2) 205 228 Price risk management 183 124 Unamortized loss, net of gain, on reacquired debt 56 63 Catastrophic event memorandum account (3) 646 656 Wildfire expense memorandum account (4) 423 423 Fire hazard prevention memorandum account (5) 261 259 Fire risk mitigation memorandum account (6) 98 95 Wildfire mitigation plan memorandum account (7) 993 558 Deferred income taxes (8) 583 252 Insurance premium costs (9) 481 — Other 739 523 Total long-term regulatory assets $ 7,507 $ 6,066 (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. Recovery of CEMA costs are subject to CPUC review and approval. (4) Includes incremental wildfire liability insurance premium costs the CPUC approved for tracking in June 2018 for the period July 26, 2017 through December 31, 2019. Recovery of WEMA costs are subject to CPUC review and approval. (5) Includes costs associated with the implementation of regulations and requirements adopted to protect the public from potential fire hazards associated with overhead power line facilities and nearby aerial communication facilities that have not been previously authorized in another proceeding. Recovery of FHPMA costs are subject to CPUC review and approval. (6) Includes costs associated with the 2019 Wildfire Mitigation Plan for the period January 1, 2019 through June 4, 2019. Recovery of FRMMA costs are subject to CPUC review and approval. (7) Includes costs associated with the 2019 Wildfire Mitigation Plan for the period June 5, 2019 through December 31, 2019 and the 2020 Wildfire Mitigation Plan for the period of January 1, 2020 through June 30, 2020. Recovery of WMPMA costs are 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 incremental liability insurance premium costs for the period January 1, 2020 through June 30, 2020. Approval of costs is pending final 2020 GRC decision. Regulatory Liabilities Long-term regulatory liabilities are comprised of the following: Balance at (in millions) June 30, 2020 December 31, 2019 Cost of removal obligations (1) $ 6,747 $ 6,456 Recoveries in excess of AROs (2) 290 393 Public purpose programs (3) 917 817 Employee benefit plans (4) 770 750 Other 917 854 Total long-term regulatory liabilities $ 9,641 $ 9,270 (1) Represents the cumulative differences between the recorded costs to remove assets and amounts collected in rates for expected costs to remove assets. (2) Represents the cumulative differences between ARO expenses and amounts collected in rates. Decommissioning costs related to the Utility’s nuclear facilities are recovered through rates and are placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on these nuclear decommissioning trust investments. (See Note 9 below.) (3) Represents amounts received from customers designated for public purpose program costs expected to be incurred beyond the next 12 months, primarily related to energy efficiency programs. (4) Represents cumulative differences between incurred costs and amounts collected in rates for Post-Retirement Medical, Post-Retirement Life and Long-Term Disability Plans. Regulatory Balancing Accounts Current regulatory balancing accounts receivable and payable are comprised of the following: Receivable Balance at (in millions) June 30, 2020 December 31, 2019 Electric distribution $ 255 $ — Electric transmission — 9 Gas distribution and transmission 119 363 Energy procurement 1,300 901 Public purpose programs 216 209 Other 748 632 Total regulatory balancing accounts receivable $ 2,638 $ 2,114 Payable Balance at (in millions) June 30, 2020 December 31, 2019 Electric distribution $ — $ 31 Electric transmission 197 119 Gas distribution and transmission 33 45 Energy procurement 731 649 Public purpose programs 547 559 Other 407 394 Total regulatory balancing accounts payable $ 1,915 $ 1,797 For more information, see Note 4 of the Notes to the Consolidated Financial Statements in Item 8 of the 2019 Form 10-K.

DEBT

DEBT	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
DEBT	DEBT Debtor-In-Possession Facilities In connection with the Chapter 11 Cases, PG&E Corporation and the Utility entered into the DIP Credit Agreement, among the Utility, as borrower, PG&E Corporation, as guarantor, JPMorgan Chase Bank, N.A. (“JPM”), as administrative agent, Citibank, N.A., as collateral agent, and the lenders and issuing banks party thereto (together with such other financial institutions from time to time party thereto, the “DIP Lenders”). On the Petition Date, PG&E Corporation and the Utility filed a motion seeking, among other things, interim and final approval of the DIP Facilities (as defined in the DIP Credit Agreement), which motion was granted on an interim basis by the Bankruptcy Court following a hearing on January 31, 2019. On March 27, 2019, the Bankruptcy Court approved the DIP Facilities on a final basis. On January 29, 2020, the Utility borrowed $500 million under the DIP Delayed Draw Term Loan Facility. On July 1, 2020, the DIP Facilities were repaid in full and all commitments thereunder were terminated in connection with emergence from Chapter 11. Debtor-in-Possession Financing The following table summarizes the Utility’s outstanding borrowings and availability under the DIP Facilities at June 30, 2020: (in millions) Termination Aggregate Limit Term Loan Borrowings Revolver Letters of Credit Outstanding Aggregate DIP Facilities December 2020 $ 5,500 $ 2,000 $ — $ 904 $ 2,596 Long-Term Debt Utility On June 19, 2020, the Utility completed the sale of (i) $500 million aggregate principal amount of Floating Rate First Mortgage Bonds due June 16, 2022, (ii) $2.5 billion aggregate principal amount of 1.75% First Mortgage Bonds due June 16, 2022, (iii) $1 billion aggregate principal amount of 2.10% First Mortgage Bonds due August 1, 2027, (iv) $2 billion aggregate principal amount of 2.50% First Mortgage Bonds due February 1, 2031, (v) $1 billion aggregate principal amount of 3.30% First Mortgage Bonds due August 1, 2040, and (vi) $1.925 billion aggregate principal amount of 3.50% First Mortgage Bonds due August 1, 2050 (collectively, the “Mortgage Bonds”). The proceeds of the Mortgage Bonds were deposited into an account at The Bank of New York Mellon Trust Company, N.A., as Escrow Agent, which proceeds were held by the Escrow Agent as collateral pursuant to an escrow agreement by and among the Escrow Agent and the Utility. As of June 30, 2020, the $8.925 billion of proceeds were included in restricted cash on the Condensed Consolidated Balance Sheets. On July 1, 2020, the net proceeds were released from escrow and, together with the net proceeds from certain other Plan financing transactions, were used to effectuate the reorganization of the Utility and PG&E Corporation in accordance with the terms and conditions contained in the Plan. On the Effective Date, pursuant to the Plan, the Utility issued $11.9 billion of its first mortgage bonds (the “New Mortgage Bonds”) in satisfaction of certain of its pre-petition senior unsecured debt, as described in the table below. On the Effective Date, pursuant to the Plan, the Utility reinstated $9.6 billion aggregate principal amount of the Utility Reinstated Senior Notes. On the Effective Date, each series of the Utility Reinstated Senior Notes was collateralized by the Utility’s delivery of a first mortgage bond in a corresponding principal amount to the applicable trustee for the benefit of the holders of the Utility Reinstated Senior Notes. The Mortgage Bonds, the New Mortgage Bonds and the Utility Reinstated Senior Notes are secured by a first lien, subject to permitted liens, on substantially all of the Utility’s real property and certain tangible property related to its facilities. The Mortgage Bonds, the New Mortgage Bonds and the Utility Reinstated Senior Notes are the Utility’s senior obligations and rank equally in right of payment with the Utility’s other existing or future first mortgage bonds issued under the Utility’s mortgage indenture. On the Effective Date, by operation of the Plan, all outstanding obligations under the Utility Short-Term Senior Notes, the Utility Long-Term Senior Notes and the Utility Funded Debt were cancelled and the applicable agreements governing such obligations were terminated. In addition, on July 1, 2020, the Utility obtained a $1.5 billion 18-month secured term loan under a term loan credit agreement. For more information, see “Credit Facilities” discussion below. PG&E Corporation On June 23, 2020, PG&E Corporation obtained a $2.75 billion secured term loan (the “Term Loan”) under a term loan credit agreement with JPM, and other lenders from time to time party thereto (collectively, the “Lenders”), JPM, as Administrative Agent and as Collateral Agent. The proceeds of the Term Loan were deposited into an account at The Bank of New York Mellon Trust Company, N.A., as Escrow Agent, which proceeds were held by the Escrow Agent as collateral pursuant to an escrow agreement by and among the Collateral Agent, the Escrow Agent, the Administrative Agent and PG&E Corporation and subsequently released from escrow on the Effective Date pursuant to the Plan. As of June 30, 2020, the $2.75 billion of proceeds were included in restricted cash on the Condensed Consolidated Balance Sheets. The Term Loan matures on June 23, 2025, unless extended by PG&E Corporation pursuant to the terms of the Term Loan Agreement. The Term Loan will bear interest based, at PG&E Corporation’s election, on (1) LIBOR (but in no event less than 1.0%) plus an applicable margin or (2) ABR (but in no event less than 2.0%) plus an applicable margin. ABR will equal the highest of the following: the prime rate, 0.5% above the overnight federal funds rate, and the one-month LIBOR plus 1.0%. The applicable margin for LIBOR loans is 4.5% and the applicable margin for ABR loans is 3.5%. PG&E Corporation may prepay the Term Loan in whole, at any time, and in part, from time to time, without premium or penalty, other than customary “breakage” costs with respect to eurodollar rate loans; provided, however, that any voluntary prepayment, refinancing or repricing of the Term Loan in connection with certain repricing transactions that occur on or prior to the first anniversary of the Effective Date shall be subject to a prepayment premium of 1.00% of the principal amount of the term loans so prepaid, refinanced or repriced. The Term Loan Agreement includes usual and customary covenants for loan agreements of this type, including covenants limiting: (1) liens, (2) mergers, (3) sales of all or substantially all of PG&E Corporation’s assets, and (4) other fundamental changes. In addition, the Term Loan Agreement requires that PG&E Corporation maintain ownership, either directly or indirectly, through one or more subsidiaries, of at least 100% of the outstanding common stock of the Utility. In the event of a default by PG&E Corporation under the Term Loan Agreement, including cross-defaults relating to specified other debt of PG&E Corporation or any of its significant subsidiaries in excess of $200 million, the Administrative Agent may, with the consent of the required Lenders (or upon the request of the required Lenders, shall), declare the amounts outstanding under the Term Loan Agreement, including all accrued interest, payable immediately. For events of default relating to insolvency, bankruptcy or receivership, the amounts outstanding under the Term Loan Agreement become payable immediately. On the Effective Date, the obligations under the Term Loan Agreement became secured by a pledge of PG&E Corporation’s ownership interest in 100% of the shares of common stock of the Utility. On July 1, 2020, the net proceeds from the Term Loan were released from escrow and were used to fund, in part, the transactions contemplated under the Plan. Additionally, on June 23, 2020, PG&E Corporation completed the sale of (i) $1.0 billion aggregate principal amount of 5.00% Senior Secured Notes due July 1, 2028 (the “2028 Notes”) and (ii) $1.0 billion aggregate principal amount of 5.25% Senior Secured Notes due July 1, 2030 (the “2030 Notes,” and together with the 2028 Notes, the “Notes”). The proceeds of the Notes were deposited into an account at The Bank of New York Mellon Trust Company, N.A., as Escrow Agent, which proceeds were held by the Escrow Agent as collateral pursuant to an escrow agreement by and among the Escrow Agent and PG&E Corporation. Prior to July 1, 2023, in the case of the 2028 Notes, and prior to July 1, 2025, in the case of the 2030 Notes, (i) PG&E Corporation may redeem all or part of the Notes of the applicable series, on any one or more occasions at a redemption price equal to 100% of the principal amount of Notes of such series to be redeemed, plus a “make-whole” premium, plus accrued and unpaid interest, if any, to, but not including, the redemption date or (ii) PG&E Corporation may redeem up to 40% of the aggregate principal amount of the Notes of the applicable series on any one or more occasions at certain specified redemption prices with the net cash proceeds from certain equity offerings. On or after July 1, 2023, in the case of the 2028 Notes, and July 1, 2025, in the case of the 2030 Notes, PG&E Corporation may redeem the Notes of a series at certain specified redemption prices, plus accrued and unpaid interest thereon, if any, to but not including, the applicable redemption date. As of June 30, 2020, the $2.0 billion of proceeds were included in restricted cash on the Condensed Consolidated Balance Sheets. On July 1, 2020, the net proceeds from the sale of the Notes were released from escrow and, together with the net proceeds from certain other Plan financing transactions, were used to effectuate the reorganization of the Corporation and the Utility in accordance with the terms and conditions contained in the Plan. The Notes are secured by a pledge of PG&E Corporation’s ownership interest in 100% of the shares of common stock of the Utility. The following table summarizes PG&E Corporation’s and the Utility’s debt: Balance at (in millions) Contractual Interest Rates June 30, 2020 December 31, 2019 Treatment under Plan on the Effective Date (1) Pre-Petition Debt (2) PG&E Corporation Borrowings under Pre-Petition Credit Facility PG&E Corporation Revolving Credit Facilities - Stated Maturity: 2022 variable rate (3) $ 300 $ 300 Repaid in cash (12) Other borrowings Term Loan - Stated Maturity: 2020 variable rate (4) 350 350 Repaid in cash (12) Less: current portion (5) (650) — Total PG&E Corporation Pre-Petition Long-Term Debt, net of current portion — 650 Utility Senior Notes - Stated Maturity: 2020 through 2022 2.45% to 4.25% 1,750 1,750 Exchanged (13) 2023 through 2028 2.95% to 4.65% 5,025 5,025 Reinstated (14) 2034 through 2040 5.40% to 6.35% 5,700 5,700 Exchanged (15) 2041 through 2042 3.75% to 4.50% 1,000 1,000 Reinstated (14) 2043 5.13% 500 500 Exchanged (15) 2043 through 2047 3.95% to 4.75% 3,550 3,550 Reinstated (14) Total Pre-Petition Senior Notes 17,525 17,525 Pollution Control Bonds - Stated Maturity: Series 2008 F and 2010 E, due 2026 1.75% 100 100 Repaid in cash (12) Series 2009 A-B, due 2026 variable rate (6) 149 149 Exchanged (16) Series 1996 C, E, F, 1997 B due 2026 variable rate (7) 614 614 Exchanged (16) Less: current portion (5) (100) — Total Pre-Petition Pollution Control Bonds, net of current portion 763 863 Borrowings under Pre-Petition Credit Facilities Utility Revolving Credit Facilities - Stated Maturity: 2022 variable rate (8) 2,888 2,888 Exchanged (16) Other borrowings: Term Loan - Stated Maturity: 2019 variable rate (9) 250 250 Exchanged (16) Total Borrowings under Pre-Petition Credit Facility 3,138 3,138 Total Utility Pre-Petition Debt, net of current portion 21,426 21,526 Total PG&E Corporation Consolidated Pre-Petition Debt, net of current portion $ 21,426 $ 22,176 New Debt PG&E Corporation Term Loan - Stated Maturity: 2025 variable rate (10) $ 2,750 $ — Senior Secured Notes due 2028 5.00% 1,000 — Senior Secured Notes due 2030 5.25% 1,000 — Unamortized discount, net of premium and debt issuance costs (93) — Total PG&E Corporation New Debt 4,657 — Utility First Mortgage Bonds - Stated Maturity: 2022 variable rate (11) 500 — 2022 1.75% 2,500 — 2027 2.10% 1,000 — 2031 2.50% 2,000 — 2040 3.30% 1,000 — 2050 3.50% 1,925 — Unamortized discount, net of premium and debt issuance costs (88) — Total Utility New Debt 8,837 — Total PG&E Corporation Consolidated New Debt $ 13,494 $ — Total Utility Long-Term Debt $ 30,263 Total PG&E Corporation Consolidated Long-Term Debt $ 34,920 (1) The treatments of pre-petition debt under the Plan, described in this column relate only to the treatment of principal amounts and not pre-petition or post-petition interest. See “Restructuring Support Agreement with the Ad Hoc Noteholder Committee” in Note 2. (2) As of December 31, 2019, debt subject to compromise was reported at the amounts expected to be allowed by the Bankruptcy Court. As of June 30, 2020, this debt is no longer subject to compromise. Total Pre-Petition Debt does not include accrued contractual interest of $280 million for the Utility to the Petition Date. Total Pre-Petition Debt also does not include post-petition interest of $25 million and $986 million for PG&E Corporation and the Utility, respectively, in accordance with the terms of the Noteholder RSA. See Note 2 for further details. (3) At June 30, 2020, the contractual LIBOR-based interest rate on loans was 1.64%. (4) At June 30, 2020, the contractual LIBOR-based interest rate on the term loan was 1.37%. (5) At June 30, 2020, the amount outstanding under PG&E Corporation’s Revolving Credit Facilities were reclassified to “Short-term borrowings” on the Condensed Consolidated Balance Sheet. At June 30, 2020, the amounts outstanding under PG&E Corporation’s Term Loan and the Utility’s Series 2008 F and 2010 E Pollution Control Bonds were reclassified to “Long-term debt, classified as current” on the Condensed Consolidated Balance Sheets. (6) At June 30, 2020, the contractual interest rate on the letter of credit facilities supporting these bonds was 6.45%. (7) At June 30, 2020, the contractual interest rate on the letter of credit facilities supporting these bonds ranged from 6.45% to 6.58%. (8) At June 30, 2020, the contractual LIBOR-based interest rate on the loans was 1.44%. (9) At June 30, 2020, the contractual LIBOR-based interest rate on the term loan was 0.77%. (10) At June 30, 2020, the contractual LIBOR-based interest rate on the loans was 5.50% (11) At June 30, 2020, the contractual LIBOR-based interest rate on the first mortgage bonds was 1.80% (12) In accordance with the Plan, these borrowings were repaid in cash on July 1, 2020. (13) In accordance with the Plan, on July 1, 2020, the Utility issued $875 million aggregate principal amount of 3.45% first mortgage bonds due 2025 and $875 million aggregate principal amount of 3.75% first mortgage bonds due 2028, in satisfaction of these Senior Notes. (14) In accordance with the Plan, these Senior Notes were reinstated on July 1, 2020. (15) In accordance with the Plan, on July 1, 2020, the Utility issued $3.1 billion aggregate principal amount of 4.55% first mortgage bonds due 2030 and $3.1 billion aggregate principal amount of 4.95% first mortgage bonds due 2050, in satisfaction of these Senior Notes. (16) In accordance with the Plan, on July 1, 2020, the Utility issued $1.95 billion aggregate principal amount of 3.15% first mortgage bonds due 2026 and $1.95 billion aggregate principal amount of 4.50% first mortgage bonds due 2040, in satisfaction of these pre-petition liabilities. Credit Facilities Utility On May 26, 2020, the Utility entered into (i) a commitment letter (the “Utility RCF Commitment Letter”) with JPM and other commitment parties thereto (the “Utility RCF Commitment Parties”) pursuant to which the Utility RCF Commitment Parties agreed, subject to the terms and satisfaction or waiver of the conditions contained therein, to provide a $3.5 billion revolving credit facility (the “Utility Revolving Credit Facility”) to the Utility and (ii) a commitment letter (the “Utility Term Loan Commitment Letter”) with JPM and the other commitment parties thereto (the “Utility Term Loan Commitment Parties”) pursuant to which the Utility Term Loan Commitment Parties agreed, subject to the terms and satisfaction or waiver of the conditions contained therein, to provide an up to $3.0 billion term loan credit facility (the “Utility Term Loan Credit Facility,” as amended on June 19, 2020) to the Utility. The Utility Revolving Credit Facility will mature in three years, subject to two one On July 1, 2020, the Utility entered into a $3.5 billion revolving credit agreement (the “Utility Revolving Credit Agreement”) with JPM, and Citibank, N.A. as co-administrative agents and Citibank, N.A., as the designated agent as contemplated by the Utility RCF Commitment Letter. The Utility Revolving Credit Agreement has a maturity date three years after the Effective Date, subject to two one Borrowings under the Utility Revolving Credit Agreement will bear interest based on the Utility’s election of either (1) LIBOR plus an applicable margin of 1.375% to 2.50% based on the Utility’s credit rating or (2) the base rate plus an applicable margin of 0.375% to 1.50% based on the Utility’s credit rating. In addition to interest on outstanding principal under the Utility Revolving Credit Agreement, the Utility is required to pay a commitment fee to the lenders in respect of the unutilized commitments thereunder, ranging from 0.25% to 0.50% per annum depending on the Utility’s credit rating. The Utility Revolving Credit Agreement has a maximum letter of credit sublimit equal to $1.5 billion. The Utility may also pay customary letter of credit fees based on letters of credit issued under the Utility Revolving Credit Agreement. The Utility’s obligations under the Utility Revolving Credit Agreement are secured by the issuance of a first mortgage bond, issued pursuant to the Utility’s mortgage indenture, secured by a first lien on substantially all of the Utility’s real property and certain tangible personal property related to its facilities, subject to certain exceptions, and which will rank pari passu with the Utility’s other first mortgage bonds. The Utility Revolving Credit Agreement includes usual and customary provisions for revolving credit agreements of this type, including covenants limiting, with certain exceptions, (1) liens, (2) indebtedness, (3) sale and leaseback transactions, and (4) other fundamental changes. In addition, the Utility Revolving Credit Agreement will require that the Utility maintain a ratio of total consolidated debt to consolidated capitalization of at most 65% as of the end of each fiscal quarter. In the event of a default by the Utility under the Utility Revolving Credit Agreement, including cross-defaults relating to specified other debt of the Utility or any of its significant subsidiaries in excess of $200 million, the designated agent may, with the consent of the required lenders (or upon the request of the required lenders, shall), declare the amounts outstanding under the Utility Revolving Credit Agreement, including all accrued interest, payable immediately. For events of default relating to insolvency, bankruptcy or receivership, the amounts outstanding under the Utility Revolving Credit Agreement become payable immediately. The Utility may voluntarily repay outstanding loans under the Utility Revolving Credit Agreement at any time without premium or penalty, other than customary “breakage” costs with respect to eurodollar rate loans. Any voluntary prepayments made by the Utility will not reduce the commitments under the Utility Revolving Credit Agreement. In addition, on July 1, 2020, the Utility obtained a $3.0 billion secured term loan under a term loan credit agreement (the “Utility Term Loan Credit Agreement”) with JPM, as administrative agent, the other lenders from time to time party thereto as contemplated by the Utility Term Loan Commitment Letter. The facilities under the Utility Term Loan Credit Agreement consist of a $1.5 billion 364-day term loan facility (the “Utility 364-Day Term Loan Facility”) and a $1.5 billion 18-month term loan facility (the “Utility 18-Month Term Loan Facility”). The maturity date for the 364-Day Term Loan Facility is June 30, 2021 and the maturity date for the 18-Month Term Loan Facility is January 1, 2022. Borrowings under the Utility Term Loan Credit Agreement will bear interest based on the Utility’s election of either (1) LIBOR plus an applicable margin of 2.00% with respect to the 364-Day Term Loan Facility and 2.25% with respect to the 18-Month Term Loan Facility, or (2) the base rate plus an applicable margin of 1.00% with respect to the 364-Day Term Loan Facility and 1.25% with respect to the Utility 18-Month Term Loan Facility. The Utility’s obligations under the Utility Term Loan Credit Agreement are secured by the issuance of first mortgage bonds, issued pursuant to the Utility’s mortgage indenture, secured by a first lien on substantially all of the Utility’s real property and certain tangible personal property related to its facilities, subject to certain exceptions, and which will rank pari passu with the Utility’s other first mortgage bonds. The Utility Term Loan Credit Agreement includes usual and customary provisions for term loan agreements of this type, including covenants limiting, with certain exceptions, (1) liens, (2) indebtedness, (3) sale and leaseback transactions, and 4) other fundamental changes. In addition, the Utility Term Loan Credit Agreement will require that the Utility maintain a ratio of total consolidated debt to consolidated capitalization of at most 65% as of the end of each fiscal quarter. In the event of a default by the Utility under the Utility Term Loan Credit Agreement, including cross-defaults relating to specified other debt of the Utility or any of its significant subsidiaries in excess of $200 million, the administrative agent may, with the consent of the required lenders (or upon the request of the required lenders, shall), declare the amounts outstanding under the Utility Term Loan Credit Agreement, including all accrued interest, payable immediately. For events of default relating to insolvency, bankruptcy or receivership, the amounts outstanding under the Utility Term Loan Credit Agreement become payable immediately. The Utility is required to prepay outstanding term loans under the Utility Term Loan Credit Agreement (with all outstanding term loans made under the Utility 364-Day Term Loan Facility being paid first), subject to certain exceptions, with 100% of the net cash proceeds of certain securitization transactions. The Utility may voluntarily repay outstanding loans under the Utility Term Loan Credit Agreement at any time without premium or penalty, other than customary “breakage” costs with respect to eurodollar rate loans. PG&E Corporation On May 26, 2020, PG&E Corporation entered into a commitment letter (the “Corporation RCF Commitment Letter”) with respect to a $500 million revolving credit facility (the “Corporation Revolving Credit Facility”), which was executed on July 1, 2020. The Corporation Revolving Credit Facility matures in three years, subject to two one On July 1, 2020, PG&E Corporation entered into a $500 million revolving credit agreement (the “Corporation Revolving Credit Agreement”) with JPM, as administrative agent and collateral agent, and the lenders from time to time party thereto as contemplated by the Corporation RCF Commitment Letter. The Corporation Revolving Credit Agreement has a maturity date three years after the Effective Date, subject to two one Borrowings under the Corporation Revolving Credit Agreement will bear interest based on PG&E Corporation’s election of either (1) LIBOR plus an applicable margin of 3.00% to 4.25% based on PG&E Corporation’s credit rating or (2) the base rate plus an applicable margin of 2.00% to 3.25% based on PG&E Corporation’s credit rating. In addition to interest on outstanding principal under the Corporation Revolving Credit Agreement, PG&E Corporation is required to pay a commitment fee to the lenders in respect of the unutilized commitments thereunder, ranging from 0.50% to 0.75% per annum depending on PG&E Corporation’s credit rating. PG&E Corporation’s obligations under the Corporation Revolving Credit Agreement are secured by a pledge of PG&E Corporation’s ownership interest in 100% of the shares of common stock of the Utility. The Corporation Revolving Credit Agreement includes usual and customary provisions for revolving credit agreements of this type, including covenants limiting, with certain exceptions, (1) liens, (2) indebtedness, (3) sale and leaseback transactions, (4) investments, (5) dispositions, (6) changes in the nature of business, (7) transactions with affiliates, (8) burdensome agreements, (9) restricted payments and (10) other fundamental changes. In addition, the Corporation Revolving Credit Agreement will require that PG&E Corporation (1) maintain a ratio of total consolidated debt to consolidated capitalization of at most 70% as of the end of each fiscal quarter and (2) if revolving loans are outstanding as of the end of a fiscal quarter, a ratio of adjusted cash to fixed charges, as of the end of such fiscal quarter, of at least 150% prior to the date that PG&E Corporation first declares a cash dividend on its common stock and at least 100% thereafter. In the event of a default by PG&E Corporation under the Corporation Revolving Credit Agreement, including cross-defaults relating to specified other debt of PG&E Corporation or any of its significant subsidiaries in excess of $200 million, the administrative agent may, with the consent of the required lenders (or upon the request of the required lenders, shall), declare the amounts outstanding under the Corporation Revolving Credit Agreement, including all accrued interest, payable immediately. For events of default relating to insolvency, bankruptcy or receivership, the amounts outstanding under the Corporation Revolving Credit Agreement become payable immediately. PG&E Corporation may voluntarily repay outstanding loans under the Corporation Revolving Credit Agreement at any time without premium or penalty, other than customary “breakage” costs with respect to eurodollar rate loans. Any voluntary repayments made by PG&E Corporation will not reduce the commitments under the Corporation Revolving Credit Agreement.

EQUITY

EQUITY	6 Months Ended
	Jun. 30, 2020
Equity [Abstract]
EQUITY	EQUITY Increase in Authorized Capitalization On June 22, 2020, PG&E Corporation filed the Amended Articles with the Secretary of State of California which increased the authorized number of shares of common stock to 3.6 billion and the authorized number of shares of preferred stock to 400 million. Plan Equity Financings In connection with emergence from Chapter 11, in July 2020, PG&E Corporation raised an aggregate of $9.0 billion of gross proceeds through the issuance of common stock and other equity-linked instruments as described below. PG&E Corporation Investment Agreement On June 7, 2020, PG&E Corporation entered into an Investment Agreement (the “Investment Agreement”) with certain investors relating to the issuance and sale to the investors of an aggregate of $3.25 billion of PG&E Corporation’s common stock. Per the Investment Agreement, the price per share was equal to $9.50 per share, which was the public equity offering price in the Common Stock Offering. On July 1, 2020, pursuant to the terms of the Investment Agreement, PG&E Corporation issued to the investors 342.1 million shares of common stock. Each investor will be subject to certain transfer restrictions, including that such investor will be restricted from transferring any shares of Common Stock purchased pursuant to the Investment Agreement (such shares, “Shares”) or engaging in hedging transactions with respect to the Shares, until the 90-day anniversary of the Effective Date, subject to certain exceptions. The investors and their affiliates will have certain customary registration rights with respect to the Shares held by such investor pursuant to the terms of the Investment Agreement. Equity Offerings On June 25, 2020, PG&E Corporation priced (i) an offering of 423.4 million shares of its common stock (the “Common Stock Offering”), and (ii) a concurrent offering of 14.5 million of its equity units (the “Equity Units”), for total net proceeds to PG&E Corporation, after deducting the underwriting discounts and before estimated offering expenses payable by the PG&E Corporation, of $3.97 billion and $1.19 billion, respectively. The Common Stock Offering and the concurrent offering of Equity Units are referred as the “Equity Offerings.” On June 25, 2020, in connection with the Common Stock Offering, the Corporation entered into an underwriting agreement (the “Common Stock Underwriting Agreement”) with Goldman Sachs & Co. LLC and J.P. Morgan Securities LLC, as representatives of several underwriters named in the Common Stock Underwriting Agreement (the “Common Stock Underwriters”), pursuant to which the Corporation agreed to issue and sell 423.4 million shares of its common stock to the Common Stock Underwriters. In addition, on June 25, 2020, the Corporation entered into an underwriting agreement (the “Equity Units Underwriting Agreement”) with Goldman Sachs & Co. LLC and J.P. Morgan Securities LLC, as representatives of the several underwriters named in the Equity Units Underwriting Agreement (the “Equity Units Underwriters”), pursuant to which PG&E Corporation agreed to issue and sell 14.5 million prepaid forward stock purchase contracts (the “Purchase Contracts”) to the Equity Underwriters in order for the Equity Units Underwriters to sell 14.5 million Equity Units. The prepaid forward stock purchase contract portion of the Equity Units offered represent the right to receive, on maturity, between 125 million and 153 million shares of PG&E Corporation common stock, subject to certain adjustments as provided therein. In connection with the Common Stock Offering and pursuant to the Common Stock Underwriting Agreement, PG&E Corporation granted the underwriters a 30-day option to purchase up to an additional 42.3 million shares of common stock. In addition, in connection with the Equity Units Offering and pursuant to the Equity Units Underwriting Agreement, the Corporation also granted the underwriters a 30-day over-allotment option to purchase up to an additional 1.45 million Purchase Contracts to be used by the Equity Units Underwriters to create up to an additional 1.45 million Equity Units (together with the 42.3 million shares of common stock, the “Option Securities”). The Common Stock Offering and the Equity Units Offering closed on July 1, 2020, and PG&E Corporation issued and sold a total of 423.4 million shares of its common stock and 14.5 million Purchase Contracts for total net proceeds of $5.2 billion. On August 3, 2020, PG&E Corporation will issue 1.45 million Equity Units to the Equity Units Underwriters pursuant to the over-allotment option in the Equity Unit Underwriting Agreement. The Common Stock Underwriters did not exercise their option to purchase any additional shares of common stock. Equity Backstop Commitments and Forward Stock Purchase Agreements See “Plan of Reorganization, and Restructuring Support Agreements, Equity Backstop Commitments and Forward Stock Purchase Agreements and Debt Commitment Letters” in Note 2 above for discussion of the equity backstop commitments which resulted in total net proceeds of $523 million. Equity Issuances to the Fire Victim Trust On the Effective Date, pursuant to the Plan, the Utility entered into an assignment agreement with the Fire Victim Trust, pursuant to which the Utility agreed to transfer to the Fire Victim Trust on the Effective Date 477 million shares of common stock of PG&E Corporation, no par value. As a result of the Equity Units Underwriters exercising their option to purchase 1.45 million additional Equity Units, on August 3, 2020, PG&E Corporation will deliver 748,415 additional shares of common stock to the Fire Victim Trust pursuant to an anti-dilution provision in the assignment agreement with the Fire Victim Trust. Contribution to the Utility Pursuant to the Plan On the Effective Date, PG&E Corporation made an equity contribution of $12.9 billion in cash, along with the Fire Victim Trust Shares, to the Utility, which used the funds and shares to satisfy and discharge certain liabilities of PG&E Corporation and the Utility under the Plan and transferred the Fire Victim Trust Shares to the Fire Victim Trust as described above. PG&E Corporation’s cash equity contribution was funded by proceeds from the financing transactions described herein. Ownership Restrictions in PG&E Corporation Articles Under Section 382 of the Internal Revenue Code (IRC), if a corporation (or a consolidated group) undergoes an “ownership change,” and the corporation does not qualify for (or elects out of) the special bankruptcy exception in Section 382(l)(5) of the Internal Revenue Code, such net operating loss carryforwards and other tax attributes may be subject to certain limitations. In general, an ownership change occurs if the aggregate stock ownership of certain shareholders (generally 5% 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). PG&E Corporation’s and the Utility’s Amended Articles limit Transfers (as defined in the Amended Articles) that increase a person’s ownership of PG&E Corporation’s equity securities to more than 4.75% prior to the Restriction Release Date without approval by the Board of Directors. The calculation of the percentage ownership may differ depending on whether the Fire Victim Trust is treated as a qualified settlement trust or grantor trust. As of the Effective Date, PG&E Corporation does not believe that it has undergone an ownership change and its net operating loss carryforwards and other tax attributes are not limited by Section 382 of the Internal Revenue Code. In 2019, $6.75 billion of the liability to be paid to the Fire Victim Trust in PG&E Corporation’s common stock was accrued by the Utility. Because the corresponding tax deduction generally occurs no earlier than payment, the Utility established a deferred tax asset for the accrual in 2019. On July 1, 2020, the Utility paid to the Fire Victim Trust 477 million shares of PG&E Corporation’s common stock. Because of the price of the stock on the date of transfer, the shares transferred to the Fire Victim Trust were valued at $4.53 billion, $2.22 billion less than the $6.75 billion that had been accrued as a liability in the Condensed Consolidated Financial Statements. Therefore, in the quarter ended June 30, 2020, the Utility recorded a charge of $619 million to adjust the measurement of the deferred tax asset to reflect the tax-effected difference between the accrual of $6.75 billion and the tax deduction of $4.53 billion for the transfer of PG&E Corporation’s shares to the Fire Victim Trust. In addition, this deferred tax asset reflects PG&E Corporation’s conclusion as of June 30, 2020 that it is more likely than not that the Fire Victim Trust will be treated as a “qualified settlement fund” for U.S. federal income tax purposes, in which case the corresponding tax deduction will have occurred at the time the PG&E Corporation common stock was transferred to the Fire Victim Trust. PG&E Corporation believes that it may be beneficial to elect to treat the Fire Victim Trust as a “grantor trust,” but only if PG&E Corporation receives favorable determinations from the IRS regarding certain aspects of such election. If PG&E Corporation makes a “grantor trust” election for the Fire Victim Trust, the Utility’s tax deduction will occur instead at the time the Fire Victim Trust pays the fire victims and will be based on the price at which the Fire Victim Trust sells the shares. In this case, the accounting treatment will require a re-evaluation under applicable accounting guidance of the remaining deferred tax asset and could result in a further impairment thereof or other material impact on the Condensed Consolidated Financial Statements. Additionally, the value of the deduction may be materially different than the value of the deduction if the Fire Victim Trust is treated as a “qualified settlement fund.” Dividends On December 20, 2017, the Boards of Directors of PG&E Corporation and the Utility suspended quarterly cash dividends on both PG&E Corporation’s and the Utility’s common stock, beginning the fourth quarter of 2017, as well as the Utility’s preferred stock, beginning the three-month period ending January 31, 2018. On April 3, 2019, the court overseeing the Utility’s probation issued an order imposing new conditions of probation, including forgoing issuing “any dividends until [the Utility] is in compliance with all applicable vegetation management requirements” under applicable law and the Utility’s Wildfire Mitigation Plan. On March 20, 2020, PG&E Corporation and the Utility filed a Case Resolution Contingency Process Motion with the Bankruptcy Court that includes a dividend restriction for PG&E Corporation. According to the dividend restriction, PG&E Corporation “will not pay common dividends until it has recognized $6.2 billion in non-GAAP core earnings following the Effective Date” of the Plan. The Bankruptcy Court entered the order approving the motion on April 9, 2020. In addition, the Corporation Revolving Credit Agreement will require that PG&E Corporation (1) maintain a ratio of total consolidated debt to consolidated capitalization of at most 70% as of the end of each fiscal quarter and (2) if revolving loans are outstanding as of the end of a fiscal quarter, a ratio of adjusted cash to fixed charges, as of the end of such fiscal quarter, of at least 150% prior to the date that PG&E Corporation first declares a cash dividend on its common stock and at least 100% thereafter. PG&E Corporation and the Utility do not expect to commence payment of dividends on its common or preferred stock upon emergence from Chapter 11. Miscellaneous On July 23, 2020, PG&E Corporation sent a notice of termination to the managers of the Amended and Restated Equity Distribution Agreement, dated as of February 17, 2017, effectively terminating the agreement on that date. During the six months ended June 30, 2020, there were no issuances under this agreement. 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.

EARNINGS PER SHARE

EARNINGS PER SHARE	6 Months Ended
	Jun. 30, 2020
Earnings Per Share [Abstract]
EARNINGS PER SHARE	EARNINGS PER SHARE PG&E Corporation’s basic EPS is calculated by dividing the income available for common shareholders by the weighted average number of common shares outstanding. PG&E Corporation applies the treasury stock method of reflecting the dilutive effect of outstanding share-based compensation in the calculation of diluted EPS. The following is a reconciliation of PG&E Corporation’s income available for common shareholders and weighted average common shares outstanding for calculating diluted EPS: Three Months Ended June 30, Six Months Ended June 30, (in millions, except per share amounts) 2020 2019 2020 2019 Loss attributable to common shareholders $ (1,972) $ (2,553) $ (1,601) $ (2,420) Weighted average common shares outstanding, basic 529 529 529 528 Add incremental shares from assumed conversions: Employee share-based compensation — — — — Weighted average common shares outstanding, diluted 529 529 529 528 Total loss per common share, diluted $ (3.73) $ (4.83) $ (3.03) $ (4.58) For each of the periods, all potentially dilutive securities were excluded from the calculation of outstanding common shares on a diluted basis as PG&E Corporation has incurred a net loss for each period presented. Following its emergence from Chapter 11, PG&E Corporation began raising funds through the issuance of equity. These issuances will materially impact the calculation of EPS in future periods. For more information on equity issuances see Note 6: Equity, above.

DERIVATIVES

DERIVATIVES	6 Months Ended
	Jun. 30, 2020
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 customer 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. By order dated April 8, 2019, the Bankruptcy Court authorized the Utility to continue these programs in the ordinary course of business in a manner consistent with its pre-petition practices. Derivatives are presented in the Utility’s Condensed Consolidated Balance Sheets recorded at fair value and on a net basis in accordance with master netting arrangements for each counterparty. The fair value of derivative instruments is further offset by cash collateral paid or received where the right of offset and the intention to offset exist. Price risk management activities that meet the definition of derivatives are recorded at fair value on the Condensed Consolidated Balance Sheets. These instruments are not held for speculative purposes and are subject to certain regulatory requirements. The Utility expects to fully recover in rates all costs related to derivatives under the applicable ratemaking mechanism in place as long as the Utility’s price risk management activities are carried out in accordance with CPUC directives. Therefore, all unrealized gains and losses associated with the change in fair value of these derivatives are deferred and recorded within the Utility’s regulatory assets and liabilities on the Condensed Consolidated Balance Sheets. Net realized gains or losses on commodity derivatives are recorded in the cost of electricity or the cost of natural gas with corresponding increases or decreases to regulatory balancing accounts for recovery from or refund to customers. The Utility elects the normal purchase and sale exception for eligible derivatives. Eligible derivatives are those that require physical delivery in quantities that are expected to be used by the Utility over a reasonable period in the normal course of business, and do not contain pricing provisions unrelated to the commodity delivered. These items are not reflected in the Condensed Consolidated Balance Sheets at fair value. Volume of Derivative Activity The volumes of the Utility’s outstanding derivatives were as follows: Contract Volume at Underlying Product Instruments June 30, 2020 December 31, 2019 Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 199,547,057 131,896,159 Options 33,810,000 14,720,000 Electricity (Megawatt-hours) Forwards, Futures and Swaps 9,754,771 18,675,852 Options 1,620,000 — Congestion Revenue Rights (3) 287,183,280 308,467,999 (1) Amounts shown are for the combined positions of the electric fuels and core gas supply portfolios. (2) Million British Thermal Units. (3) CRRs are financial instruments that enable the holders to manage variability in electric energy congestion charges due to transmission grid limitations. Presentation of Derivative Instruments in the Financial Statements At June 30, 2020, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Balance Current assets – other $ 46 $ (7) $ 29 $ 68 Other noncurrent assets – other 121 — — 121 Current liabilities – other (44) 7 — (37) Noncurrent liabilities – other (183) — — (183) Total commodity risk $ (60) $ — $ 29 $ (31) At December 31, 2019, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 36 $ (6) $ 4 $ 34 Other noncurrent assets – other 130 (6) — 124 Current liabilities – other (31) 6 2 (23) Noncurrent liabilities – other (130) 6 — (124) Total commodity risk $ 5 $ — $ 6 $ 11 Cash inflows and outflows associated with derivatives are included in operating cash flows on the Utility’s Condensed Consolidated Statements of Cash Flows.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	6 Months Ended
	Jun. 30, 2020
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 June 30, 2020 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 718 $ — $ — $ — $ 718 Nuclear decommissioning trusts Short-term investments 34 — — — 34 Global equity securities 2,135 — — — 2,135 Fixed-income securities 794 753 — — 1,547 Assets measured at NAV — — — — 20 Total nuclear decommissioning trusts (2) 2,963 753 — — 3,736 Price risk management instruments (Note 8) Electricity — 14 148 21 183 Gas — 5 — 1 6 Total price risk management instruments — 19 148 22 189 Rabbi trusts Fixed-income securities — 105 — — 105 Life insurance contracts — 77 — — 77 Total rabbi trusts — 182 — — 182 Long-term disability trust Short-term investments 6 — — — 6 Assets measured at NAV — — — — 150 Total long-term disability trust 6 — — — 156 TOTAL ASSETS $ 3,687 $ 954 $ 148 $ 22 $ 4,981 Liabilities: Equity Backstop Commitments and Forward Stock Purchase Agreements $ — $ 1,500 $ — $ — $ 1,500 Price risk management instruments (Note 8) Electricity — 9 214 (6) 217 Gas — 4 — (1) 3 TOTAL LIABILITIES $ — $ 1,513 $ 214 $ (7) $ 1,720 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $540 million, primarily related to deferred taxes on appreciation of investment value. Fair Value Measurements December 31, 2019 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 1,323 $ — $ — $ — $ 1,323 Nuclear decommissioning trusts Short-term investments 6 — — — 6 Global equity securities 2,086 — — — 2,086 Fixed-income securities 862 728 — — 1,590 Assets measured at NAV — — — — 21 Total nuclear decommissioning trusts (2) 2,954 728 — — 3,703 Price risk management instruments (Note 8) Electricity — 2 161 (11) 152 Gas — 3 — 3 6 Total price risk management instruments — 5 161 (8) 158 Rabbi trusts Fixed-income securities — 100 — — 100 Life insurance contracts — 73 — — 73 Total rabbi trusts — 173 — — 173 Long-term disability trust Short-term investments 10 — — — 10 Assets measured at NAV — — — — 156 Total long-term disability trust 10 — — — 166 TOTAL ASSETS $ 4,287 $ 906 $ 161 $ (8) $ 5,523 Liabilities: Price risk management instruments (Note 8) Electricity $ 1 $ 2 $ 156 $ (13) $ 146 Gas — 2 — (1) 1 TOTAL LIABILITIES $ 1 $ 4 $ 156 $ (14) $ 147 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $530 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 three and six months ended June 30, 2020 and 2019. Trust Assets Assets Measured at Fair Value In general, investments held in the trusts are exposed to various risks, such as interest rate, credit, and market volatility risks. Nuclear decommissioning trust assets and other trust assets are composed primarily of equity and fixed-income securities and also include short-term investments that are money market funds valued as Level 1. Global equity securities primarily include investments in common stock that are valued based on quoted prices in active markets and are classified as Level 1. Fixed-income securities are primarily composed of U.S. government and agency securities, municipal securities, and other fixed-income securities, including corporate debt securities. U.S. government and agency securities primarily consist of U.S. Treasury securities that are classified as Level 1 because the fair value is determined by observable market prices in active markets. A market approach is generally used to estimate the fair value of fixed-income securities classified as Level 2 using evaluated pricing data such as broker quotes, for similar securities adjusted for observable differences. Significant inputs used in the valuation model generally include benchmark yield curves and issuer spreads. The external credit ratings, coupon rate, and maturity of each security are considered in the valuation model, as applicable. Assets Measured at NAV Using Practical Expedient Investments in the nuclear decommissioning trusts and the long-term disability trust that are measured at fair value using the NAV per share practical expedient have not been classified in the fair value hierarchy tables above. The fair value amounts are included in the tables above in order to reconcile to the amounts presented in the Condensed Consolidated Balance Sheets. These investments include commingled funds that are composed of equity securities traded publicly on exchanges as well as fixed-income securities that are composed primarily of U.S. government securities 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. Market and credit risk management 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. Equity Backstop Commitments and Forward Stock Purchase Agreements The Equity Backstop Commitments and Forward Stock Purchase Agreements are defined as financial instruments with both the Backstop Premium Shares and the Additional Backstop Premium Shares measurable at fair value on each reporting period. PG&E Corporation used market observable inputs to derive the fair value as of the reporting date. As of June 30, 2020, PG&E Corporation recorded approximately $1.1 billion of expense related to the Backstop Premium Shares and approximately $444 million of expense related to the Additional Backstop Premium Shares in Reorganization items, net on the Condensed Consolidated Statements of Income. The associated liabilities are classified as Level 2. For more information regarding the Backstop Commitments premium and Forward Stock Purchase Agreements, see “Equity Backstop Commitments and Forward Stock Purchase Agreements ” in Note 2 above. 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 customer rates; therefore, there is no impact to net income resulting from changes in the fair value of these instruments. (See Note 8 above.) Fair Value at (in millions) June 30, 2020 Fair Value Measurement Assets Liabilities Valuation Unobservable Range (1) / Weighted-Average Price (2) Congestion revenue rights $ 135 $ 59 Market approach CRR auction prices $(23.93) - $25.51 / 0.27 Power purchase agreements $ 13 $ 155 Discounted cash flow Forward prices $11.83 - $64.30 / 31.81 (1) Represents price per megawatt-hour. (2) Unobservable inputs were weighted by the relative fair value of the instruments. Fair Value at (in millions) December 31, 2019 Fair Value Measurement Assets Liabilities Valuation Technique Unobservable Input Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 140 $ 44 Market approach CRR auction prices $(20.20) - $20.20 / 0.28 Power purchase agreements $ 21 $ 112 Discounted cash flow Forward prices $11.77 - $59.38 / 33.62 (1) Represents price per megawatt-hour. (2) Unobservable inputs were weighted by the relative fair value of the instruments. Level 3 Reconciliation The following table presents the reconciliation for Level 3 instruments for the three and six months ended June 30, 2020 and 2019: Price Risk Management Instruments (in millions) 2020 2019 Asset (liability) balance as of April 1 $ (5) $ 129 Net realized and unrealized losses: Included in regulatory assets and liabilities or balancing accounts (1) (61) (20) Asset (liability) balance as of June 30 $ (66) $ 109 (1) The costs related to price risk management activities are fully passed through to customers in rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted. Price Risk Management Instruments (in millions) 2020 2019 Asset balance as of January 1 $ 5 $ 95 Net realized and unrealized gains (losses): Included in regulatory assets and liabilities or balancing accounts (1) (71) 14 Asset (liability) balance as of June 30 $ (66) $ 109 (1) The costs related to price risk management activities are fully passed through to customers in rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted. Financial Instruments PG&E Corporation and the Utility use the following methods and assumptions in estimating fair value for financial instruments: the fair values of cash, net accounts receivable; short-term borrowings; accounts payable; and customer deposits approximate their carrying values at June 30, 2020 and December 31, 2019, as they are short-term in nature. The carrying amount and fair value of PG&E Corporation’s and the Utility’s long-term debt instruments were as follows (the table below excludes financial instruments with carrying values that approximate their fair values): At June 30, 2020 At December 31, 2019 (in millions) Carrying Amount Level 2 Fair Value Carrying Amount (1) Level 2 Fair Value (1)(2) Debt (Note 5) PG&E Corporation $ 2,257 $ 2,005 $ — $ — Utility 25,962 28,853 1,500 1,500 (1) On January 29, 2019 PG&E Corporation and the Utility filed for Chapter 11 protection. Debt held by PG&E Corporation and the Utility became debt subject to compromise and is valued at the allowed claim amount. For more information, see Note 2 and Note 5. (2) The fair value of the Utility pre-petition debt was $17.9 billion at December 31, 2019. For more information, see Note 2 and Note 5. Nuclear Decommissioning Trust Investments The following table provides a summary of equity securities and available-for-sale debt securities: (in millions) As of June 30, 2020 Amortized Total Unrealized Gains Total Unrealized Losses Total Fair Nuclear decommissioning trusts Short-term investments $ 34 $ — $ — $ 34 Global equity securities 646 1,524 (15) 2,155 Fixed-income securities 1,386 165 (4) 1,547 Total (1) $ 2,066 $ 1,689 $ (19) $ 3,736 As of December 31, 2019 Nuclear decommissioning trusts Short-term investments $ 6 $ — $ — $ 6 Global equity securities 500 1,609 (2) 2,107 Fixed-income securities 1,505 89 (4) 1,590 Total (1) $ 2,011 $ 1,698 $ (6) $ 3,703 (1) Represents amounts before deducting $540 million and $530 million for the periods ended June 30, 2020 and December 31, 2019, respectively, primarily related to deferred taxes on appreciation of investment value. The fair value of fixed-income securities by contractual maturity is as follows: As of (in millions) June 30, 2020 Less than 1 year $ 28 1–5 years 416 5–10 years 404 More than 10 years 699 Total maturities of fixed-income securities $ 1,547 The following table provides a summary of activity for fixed income and equity securities: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2020 2019 2020 2019 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 254 $ 171 $ 787 $ 517 Gross realized gains on securities 8 56 26 22 Gross realized losses on securities (12) (26) (21) (7)

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES	6 Months Ended
	Jun. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
WILDFIRE-RELATED CONTINGENCIES	WILDFIRE-RELATED CONTINGENCIES PG&E Corporation and the Utility have significant contingencies arising from their operations, including contingencies related to wildfires. A provision for a loss contingency is recorded when it is both probable that a liability has been incurred and the amount of the liability can be reasonably estimated. PG&E Corporation and the Utility evaluate which potential liabilities are probable and the related range of reasonably estimated losses and record a charge that reflects their best estimate or the lower end of the range, if there is no better estimate. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of losses is estimable, often involves a series of complex judgments about future events. Loss contingencies are reviewed quarterly, and estimates are adjusted to reflect the impact of all known information, such as negotiations, discovery, settlements and payments, rulings, advice of legal counsel, and other information and events pertaining to a particular matter. PG&E Corporation’s and the Utility’s provision for loss and expense excludes anticipated legal costs, which are expensed as incurred. PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows may be materially affected by the outcome of the following matters. 2015 Butte Fire In September 2015, a wildfire (the “2015 Butte fire”) ignited and spread in Amador and Calaveras Counties in Northern California. Cal Fire concluded that the 2015 Butte fire was caused when a gray pine tree contacted the Utility’s electric line, which ignited portions of the tree, and determined that the failure by the Utility and/or its vegetation management contractors, ACRT Inc. and Trees, Inc., to identify certain potential hazards during its vegetation management program ultimately led to the failure of the tree. See “Pre-Petition Wildfire-Related Claims and Discharge Upon Plan Effective Date” and “District Attorney’s Office Investigations” below for more information on the 2015 Butte fire. 2018 Camp Fire and 2017 Northern California Wildfires Background According to Cal Fire, on November 8, 2018 at approximately 6:33 a.m., a wildfire began near the city of Paradise, Butte County, California (the “2018 Camp fire”), which is located in the Utility’s service territory. Cal Fire’s Camp Fire Incident Information Website as of November 15, 2019 (the “Cal Fire website”) indicated that the 2018 Camp fire consumed 153,336 acres. On the Cal Fire website, Cal Fire reported 85 fatalities and the destruction of 18,804 structures resulting from the 2018 Camp fire. Beginning on October 8, 2017, multiple wildfires spread through Northern California, including Napa, Sonoma, Butte, Humboldt, Mendocino, Lake, Nevada, and Yuba Counties, as well as in the area surrounding Yuba City (the “2017 Northern California wildfires”). According to the Cal Fire California Statewide Fire Summary dated October 30, 2017, at the peak of the 2017 Northern California wildfires, there were 21 major fires that, in total, burned over 245,000 acres and destroyed an estimated 8,900 structures. The 2017 Northern California wildfires resulted in 44 fatalities. As described below under the heading “Restructuring Support Agreement with the TCC,” on December 6, 2019, PG&E Corporation and the Utility entered into a RSA with the TCC, the Consenting Fire Claimant Professionals and the Shareholder Proponents to potentially resolve all wildfire-related claims relating to the 2017 Northern California wildfires and the 2018 Camp fire (other than subrogated insurance claims and Public Entity Wildfire Claims) through the Chapter 11 process. On December 19, 2019, the Bankruptcy Court entered an order approving the TCC RSA. As described below under the heading “Restructuring Support Agreement with Holders of Subrogation Claims,” on September 22, 2019, PG&E Corporation and the Utility entered into a RSA with certain holders of insurance subrogation claims to potentially resolve all insurance subrogation claims relating to the 2017 Northern California wildfires and the 2018 Camp fire through the Chapter 11 process. On December 19, 2019, the Bankruptcy Court entered an order approving the Subrogation RSA. As described below under the heading “Plan Support Agreements with Public Entities,” on June 18, 2019, PG&E Corporation and the Utility entered into agreements with certain government entities to potentially resolve their wildfire-related claims through the Chapter 11 process. The PSAs do not require Bankruptcy Court approval to be effective; however, Bankruptcy Court approval of the Plan that incorporates the terms of the PSAs was required. The Bankruptcy Court confirmed the Plan on June 20, 2020. On April 21, 2020, the parties announced that settlement agreements had been reached with certain Federal agencies (including FEMA and the United States Small Business Administration (the “SBA”)) and certain State agencies (including Cal OES and Cal Fire) regarding their claims filed against PG&E Corporation or the Utility in the Chapter 11 Cases which constitute “Fire Claims” (as defined in the Plan). Pursuant to the terms of the settlement agreements: • the Fire Claims of FEMA and the SBA were allowed at $1 billion, channeled to the Fire Victim Trust, and fully subordinated and made junior in right of payment to the prior payment in full of all other Fire Victim Claims from the Fire Victim Trust; • $117 million will be paid to the DOJ in full and final satisfaction and discharge of the Fire Claims of certain other Federal agencies and payable solely from the proceeds of the “Assigned Rights and Causes of Action” (as defined in the Plan), after the payment of professional fees and costs incurred in connection with the prosecution of such Assigned Rights and Causes of Action; • Cal OES’s Fire Claims were withdrawn with prejudice; • Cal Fire’s Fire Claims were allowed at $115.3 million (the “Cal Fire Settlement Amount”), payable over a period of years by the Fire Victim Trust, with the first $70 million payable solely and exclusively from any cash interest earned on the cash holdings of the Fire Victim Trust after the Effective Date and the remaining $45.3 million payable solely and exclusively from such cash interest less the expenses of administering the Fire Victim Trust in such years; • the Fire Claims of certain other State agencies were allowed at $89 million, payable by the Fire Victim Trust over a period of years, with the first $60 million payable solely and exclusively from proceeds of the monetization of the PG&E Corporation common stock in excess of $6.75 billion in accordance with an agreed-upon formula and available cash interest after expenses and after the Cal Fire Settlement Amount has been paid in full, and the balance payable solely and exclusively from such monetization proceeds and interest earned on the cash holdings of the Fire Victim Trust (less expenses of administering the Fire Victim Trust); and • the holders of the above claims that are being settled and channeled to the Fire Victim Trust, consistent with the Plan, have no right of recovery from PG&E Corporation or the Utility. Consistent with the Plan and the agreements, the obligations of payment relating to the agreements are solely the responsibility of the Fire Victim Trust, and PG&E Corporation and the Utility will have no further obligations with respect to the claims that are the subject of the agreements. PG&E Corporation and the Utility filed a motion seeking Bankruptcy Court approval of the settlement agreements on April 26, 2020, and the Bankruptcy Court approved the settlement agreements on May 18, 2020. Pre-petition Wildfire-Related Claims and Discharge Upon Plan Effective Date Pre-petition wildfire-related claims on the Condensed Consolidated Financial Statements include amounts associated with the 2018 Camp fire, the 2017 Northern California wildfires, and the 2015 Butte fire. At June 30, 2020 and December 31, 2019, the Utility’s Consolidated Balance Sheets include estimated liabilities in respect of total wildfire-related claims of $25.5 billion. The aggregate liability of $25.5 billion for claims in connection with the 2018 Camp fire, the 2017 Northern California wildfires, and the 2015 Butte fire is comprised of (i) $11 billion for subrogated insurance claimholders pursuant to the Subrogation RSA, plus (ii) $47.5 million for expected professional fees for professionals retained by subrogated insurance claimholders to be reimbursed pursuant to the Subrogation RSA, plus (iii) $1 billion for the Supporting Public Entities with respect to their Public Entity Wildfire Claims pursuant to the PSAs, plus (iv) $13.5 billion for all other wildfire-related claims, including individual wildfire claimholders (including those with uninsured and underinsured property losses) and clean-up and fire suppression costs, pursuant to the TCC RSA. The aggregate liability of $25.5 billion for claims in connection with the 2018 Camp fire, the 2017 Northern California wildfires and the 2015 Butte fire corresponded PG&E Corporation’s and the Utility’s best estimate of probable losses. On July 1, 2020, pursuant to the Plan, PG&E Corporation and the Utility funded the Fire Victim Trust with $5.4 billion in cash (with an additional $1.35 billion to be funded on a deferred basis), 477.0 million shares of common stock of PG&E Corporation (representing 22.19% of the outstanding common stock of PG&E Corporation as of the Effective Date (subject to potential adjustments)), plus the assignment of certain rights and causes of action. In accordance with the Plan and the Confirmation Order, as a result of such funding, all Fire Victim Claims (as defined in the Plan) have been satisfied, released and discharged and channeled to the Fire Victim Trust with no recourse to PG&E Corporation or the Utility. Accordingly, $12.15 billion of the $13.5 billion liability as of June 30, 2020 will be extinguished in the third quarter of 2020, and the remaining $1.35 billion will be paid out under the terms of the Tax Benefits Payment Agreement, as described in Note 2 under the heading “Chapter 11 Claims Process.” On July 1, 2020, PG&E Corporation and the Utility funded the Subrogation Wildfire Trust for the benefit of insurance subrogation claimants in the amount of $11.0 billion in cash and paid approximately $43 million in respect of professional fees of such claimants, for a total of approximately $52 million for claimants’ professional fees. Such amount was initially funded into escrow and later paid to the Subrogation Wildfire Trust. In accordance with the Plan and the Confirmation Order, as a result of such funding, all insurance subrogation claims have been satisfied, released and discharged and channeled to the Subrogation Wildfire Trust with no recourse to PG&E Corporation or the Utility. Accordingly, the $11.0 billion liability accrual for subrogated insurance claims and $47.5 million liability for professional fees will be extinguished in the third quarter of 2020. On July 1, 2020, PG&E Corporation and the Utility paid $1.0 billion in cash to the Settling Public Entities and established a segregated fund in the amount of $10 million to be used to reimburse the Settling Public Entities for any and all legal fees and costs associated with the defense or resolution of any third party claims against the Settling Public Entities. In accordance with the Plan and the Confirmation Order, as a result of such payments, the Public Entity Wildfire Claims have been satisfied, released and discharged. Accordingly, the $1.0 billion liability for Public Entity Wildfire Claims will be extinguished in the third quarter of 2020. In addition, during the three and six months ended June 30, 2020, the Utility incurred legal and other costs of $24 million and $58 million, respectively, related to the 2018 Camp fire, the 2017 Northern California wildfires and the 2015 Butte fire, as compared to $26 million and $73 million, respectively, during the same periods in 2019. During the three and six months ended June 30, 2020, the Utility incurred legal and other costs of $2 million related to the 2019 Kincade fire. Plan Support Agreements with Public Entities On June 18, 2019, PG&E Corporation and the Utility entered into PSAs with certain local public entities (collectively, the “Supporting Public Entities”) providing for an aggregate of $1.0 billion to be paid by PG&E Corporation and the Utility to such public entities pursuant to the Plan in order to settle and discharge such public entities’ claims against PG&E Corporation and the Utility relating to the 2018 Camp fire, 2017 Northern California wildfires and 2015 Butte fire (collectively, “Public Entity Wildfire Claims”). The PSAs also provide that, following the Effective Date, PG&E Corporation and the Utility will create and promptly fund $10.0 million to a segregated fund (the “Public Entity Segregated Defense Fund”) to be used by the Supporting Public Entities collectively in connection with the defense or resolution of claims against the Supporting Public Entities by third parties relating to the wildfires noted above (“Third Party Claims”). These elements were incorporated into the Plan which was approved by the Bankruptcy Court in the Confirmation Order. As described in “Chapter 11 Claims Process” above, the actions required by each PSA were taken on or around the Effective Date. Restructuring Support Agreement with Holders of Subrogation Claims On September 22, 2019, PG&E Corporation and the Utility entered into the Subrogation RSA. The Subrogation RSA provides for an aggregate amount of $11.0 billion (the “Aggregate Subrogation Recovery”) to be paid by PG&E Corporation and the Utility pursuant to the Plan in order to settle the Subrogation Claims, upon the terms and conditions set forth in the Subrogation RSA. Under the Subrogation RSA, PG&E Corporation and the Utility have also agreed to reimburse the holders of Subrogation Claims for professional fees of up to $55 million, upon the terms and conditions set forth in the Subrogation RSA. As described above under the heading “Pre-petition Wildfire-Related Claims and Discharge Upon Plan Effective Date,” the payments described in the Subrogation RSA were made on the Effective Date. Restructuring Support Agreement with the TCC On December 6, 2019, PG&E Corporation and the Utility entered into the TCC RSA. The TCC RSA provides for, among other things, a combination of cash and common stock of the reorganized PG&E Corporation to be provided by PG&E Corporation and the Utility pursuant to the Plan (together with certain additional rights, the “Aggregate Fire Victim Consideration”) in order to settle and discharge the Fire Victim Claims, upon the terms and conditions set forth in the TCC RSA and the Plan. The Aggregate Fire Victim Consideration to be funded into the Fire Victim Trust to be established pursuant to the Plan for the benefit of holders of the Fire Victim Claims will consist of (a) $5.4 billion in cash to be contributed on the Effective Date of the Plan, (b) $1.35 billion in cash consisting of (i) $650 million to be paid in cash on or before January 15, 2021 and (ii) the remaining balance of $1.35 billion to be paid in cash on or before January 15, 2022, in each case pursuant to the terms of a tax benefit payment agreement to be entered into between the Fire Victim Trust and the reorganized Utility, and (c) an amount of common stock of the reorganized PG&E Corporation valued at 14.9 times Normalized Estimated Net Income (as defined in the TCC RSA), except that the Fire Victim Trust’s share ownership of the reorganized PG&E Corporation will not be less than 20.9% based on the number of fully diluted shares of the reorganized PG&E Corporation outstanding as of the Effective Date of the Plan, assuming the Utility’s allowed ROE as of the date of the TCC RSA. Under certain circumstances, including certain change of control transactions and in connection with the monetization of certain tax benefits related to the payment of wildfire-related claims, the payments described in clause (b) will be accelerated and payable upon an earlier date. The Aggregate Fire Victim Consideration also includes (1) the assignment by PG&E Corporation and the Utility to the Fire Victim Trust of certain rights and causes of action related to the 2015 Butte fire, the 2017 Northern California wildfires and the 2018 Camp fire (together, the “Fires”) that PG&E Corporation and the Utility may have against certain third parties and (2) the assignment of rights under the 2015 insurance policies to resolve any claims related to the Fires in those policy years, other than the rights of PG&E Corporation and the Utility to be reimbursed under the 2015 insurance policies for claims submitted to and paid by PG&E Corporation and the Utility prior to the Petition Date to resolve any claims related to the Fires in those policy years. On June 11, 2020, PG&E Corporation and the Utility and the TCC agreed that the percentage ownership of the Fire Victim Trust will be 22.19% of the outstanding shares of the PG&E Corporation on the Effective Date. Pursuant to further discussions with claimants relating to the Ghost Ship fire, certain provisions of the TCC RSA were superseded by the terms of the Plan, and accordingly the above description of the TCC RSA has been revised to reflect the fact that claims arising out of the Ghost Ship fire will be resolved separately from the TCC RSA. As described above under the heading “Pre-petition Wildfire-Related Claims and Discharge Upon Plan Effective Date,” the funding to be made pursuant to the TCC RSA and the Plan were made on the Effective Date. 2019 Kincade Fire According to Cal Fire, on October 23, 2019 at approximately 9:27 p.m., a wildfire began northeast of Geyserville in Sonoma County, California (the “2019 Kincade fire”), located in the service territory of the Utility. The Cal Fire Kincade Fire Incident Update dated November 20, 2019, 11:02 a.m. Pacific Time (the “incident update”) indicated that the 2019 Kincade fire had consumed 77,758 acres. In the incident update, Cal Fire reported no fatalities and four first responder injuries. The incident update also indicates the following: structures destroyed, 374 (consisting of 174 residential structures, 11 commercial structures and 189 other structures); and structures damaged, 60 (consisting of 35 residential structures, one commercial structure and 24 other structures). In connection with the 2019 Kincade fire, state and local officials issued numerous mandatory evacuation orders and evacuation warnings at various times for certain areas of the region. 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 October 23, 2019, by 3:00 p.m. Pacific Time, the Utility had conducted a PSPS event and turned off the power to approximately 27,837 customers in Sonoma County, including Geyserville and the surrounding area. As part of the PSPS, the Utility’s distribution lines in these areas were deenergized. Following the Utility’s established and CPUC-approved PSPS protocols and procedures, transmission lines in these areas remained energized. The Utility has submitted electric incident reports to the CPUC indicating that: • at approximately 9:19 p.m. Pacific Time on October 23, 2019, the Utility became aware of a transmission level outage on the Geysers #9 Lakeville 230 kV line when the line relayed and did not reclose; • various generating facilities on the Geysers #9 Lakeville 230kV line detected the disturbance and separated at approximately the same time; • at approximately 9:21 p.m. Pacific Time, the PG&E Grid Control Center received a report that a fire had started in an area near transmission tower 001/006; • at approximately 7:30 a.m. Pacific Time on October 24, 2019, a responding Utility troubleman patrolling the Geysers #9 Lakeville 230 kV line observed that Cal Fire had taped off the area around the base of transmission tower 001/006 in the area of the 2019 Kincade fire; and • on site Cal Fire personnel brought to the troubleman’s attention what appeared to be a broken jumper on the same tower. On July 16, 2020, Cal Fire issued a press release addressing the cause of the 2019 Kincade fire. Cal Fire has determined that “the Kincade Fire was caused by electrical transmission lines owned and operated by Pacific Gas and Electric (PG&E) located northeast of Geyserville. Tinder dry vegetation and strong winds combined with low humidity and warm temperatures contributed to extreme rates of fire spread.” Cal Fire also indicated that its investigative report has been forwarded to the Sonoma County District Attorney’s Office, which is reviewing the matter. PG&E Corporation and the Utility are also conducting their own investigation into the cause of the 2019 Kincade fire. This investigation is preliminary, and PG&E Corporation and the Utility do not have access to all of the evidence in the possession of Cal Fire or other third parties. Potential liabilities related to the Kincade Fire depend on various factors, including but not limited to the cause of the fire, contributing causes of the fire (including alternative potential origins, weather- and climate-related issues), 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, 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 or fines that may be imposed by governmental entities. If the Utility’s facilities, such as its electric distribution and transmission lines, are judicially determined to be the substantial cause of the Kincade fire, 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 from their customers. 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. (See “Loss Recoveries – Regulatory Recovery” below for further information regarding potential cost recovery related to the wildfires.) In light of the current state of the law concerning inverse condemnation and the information currently available to PG&E Corporation and the Utility as of the date of this filing, including the information contained in the electric incident reports, Cal Fire’s determination of the cause, and other 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 of at least $600 million in connection with the 2019 Kincade fire (before available insurance). This amount corresponds to the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimable range of losses and is subject to change based on additional information. The $600 million estimate does not include, among other things, (i) any amounts for potential penalties or fines that may be imposed by governmental entities on PG&E Corporation or the Utility, (ii) any punitive damages, (iii) any amounts in respect of compensation claims by Federal, state, county and local government entities or agencies other than state fire suppression costs, (iv) evacuation costs or (v) any other amounts that are not reasonably estimable. PG&E Corporation and the Utility currently believe that it is reasonably possible that the amount of loss could be greater than $600 million (before available insurance) but are unable to reasonably estimate the additional loss and the upper end of the range because, as described above, there are a number of unknown facts and legal considerations that may impact the amount of any potential liability, including the total scope and nature of claims that may be asserted against PG&E Corporation and the Utility. If the liability for the 2019 Kincade fire were to exceed $1.0 billion, it is possible the Utility would be eligible to make a claim to the Wildfire Fund under AB 1054 for such excess amount, subject to the 40% limitation on 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 Cal Fire’s possession, evidence from or held by other parties, claims that have not yet been submitted, and additional information about the nature and extent of potential damages. The process for estimating losses associated with potential claims related to the 2019 Kincade fire requires management to exercise significant judgment based on a number of assumptions and subjective factors, including the factors identified above and estimates based on currently available information and prior experience with wildfires. As more information becomes available, management estimates and assumptions regarding the potential financial impact of the 2019 Kincade fire may change. The Utility has liability insurance from various insurers, which provides coverage for third-party liability attributable to the Kincade fire in an aggregate amount of $430 million. The Utility records insurance recoveries when it is deemed probable that recovery will occur, and the Utility can reasonably estimate the amount or its range. As of June 30, 2020, the Utility has recorded an insurance receivable for the full amount of the $430 million. While the Utility plans to seek recovery of all insured losses, it is unable to predict the ultimate amount and timing of such insurance recoveries. PG&E Corporation and the Utility have received and are responding to data requests from the SED relating to the Kincade fire. Various other entities, including law enforcement agencies, may also be investigating the fire. It is uncertain when the investigations will be complete. As of July 24, 2020, PG&E Corporation and the Utility are aware of three complaints on behalf of approximately 142 plaintiffs related to the 2019 Kincade fire and expects that they may receive further such complaints. The complaints were filed in the California Superior Court for the County of Sonoma and include claims based on multiple theories of liability, including inverse condemnation, negligence, violations of the Public Utilities Code, violations of the Health & Safety Code, premises liability, trespass, public nuisance and private nuisance. The plaintiffs in each action principally assert that PG&E Corporation’s and the Utility’s alleged failure to properly maintain, inspect and de-energize their transmission lines was the cause of the 2019 Kincade fire. The plaintiffs seek damages that include property damage, economic loss, punitive damages, exemplary damages, attorneys’ fees and other damages. In addition to claims for property damage, business interruption, interest and attorneys’ fees, 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, including if the Utility were found to have been negligent. Loss Recoveries PG&E Corporation and the Utility have insurance coverage for liabilities, including wildfire. Additionally, there are several mechanisms that allow for recovery of costs from customers. Potential for recovery is described below. Failure to obtain a substantial or full recovery of costs related to the 2018 Camp fire and 2017 Northern California wildfires or any conclusion that such recovery is no longer probable could have a material effect on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows. In addition, the inability to recover costs in a timely manner could have a material effect on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows. Insurance Insurance Coverage PG&E Corporation and the Utility have liability insurance coverage for wildfire events in an amount of $430 million (subject to an initial self-insured retention of $10 million per occurrence) for the period from August 1, 2019 through July 31, 2020, and approximately $1 billion in liability insurance coverage for non-wildfire events (subject to an initial self-insured retention of $10 million per occurrence), comprised of $520 million for the period from August 1, 2019 through July 31, 2020 and $480 million for the period from September 3, 2019 through September 2, 2020. PG&E Corporation’s and the Utility’s cost of obtaining this wildfire and non-wildfire insurance coverage in place for the period of August 1, 2019 through September 2, 2020 is approximately $212 million. In July 2020, the Utility renewed its liability insurance coverage for wildfire events in the amount of $757.5 million (subject to an initial self-insured retention of $60 million), comprised of $715 million for the period of August 1, 2020 to July 31, 2021 and $42.5 million in reinsurance for the period of July 1, 2020 through June 30, 2021. In addition, the Utility renewed its liability insurance coverage for non-wildfire events in the amount of $700 million (subject to an initial self-insured retention of $10 million) for the period from August 1, 2020 through July 31, 2021. PG&E Corporation and the Utility’s cost of obtaining this wildfire and non-wildfire coverage is approximately $749 million. PG&E Corporation and the Utility continue to pursue additional insurance coverage for the period from August 1, 2020 through July 31, 2021. Various coverage limitations applicable to different insurance layers could result in material uninsured costs in the future depending on the amount and type of damages resulting from covered events. The Utility’s 2020 GRC settlement agreement, currently pending before the Commission, includes a new two-way balancing account that, if approved, would allow the Utility to recover in rates its actual insurance premium costs for up to $1.4 billion in coverage. The Utility is unable to predict the timing and outcome of the 2020 GRC proceeding. The Utility will not be able to obtain any recovery from the Wildfire Fund for wildfire-related losses in any calendar year that do not exceed the greater of $1.0 billion in the aggregate and the amount of insurance coverage required under AB 1054. Insurance Receivable PG&E Corporation and the Utility record a receivable for insurance recoveries when it is deemed probable that recovery of a recorded loss will occur. Through June 30, 2020, PG&E Corporation and the Utility recorded $1.38 billion for probable insurance recoveries in connection with the 2018 Camp fire, $843 million for probable insurance recoveries in connection with the 2017 Northern California wildfires, and $430 million for probable insurance recoveries in connection with the 2019 Kincade fire. These amounts reflect an assumption that the cause of each fire is deemed to be a separate occurrence under the insurance policies. PG&E Corporation and the Utility intend to seek full recovery for all insured losses. If PG&E Corporation and the Utility are unable to recover the full amount of their insurance, PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows could be materially affected. Even if PG&E Corporation and the Utility were to recover the full amount of their insurance, PG&E Corporation and the Utility expect their losses in connection with the 2018 Camp fire and the 2017 Northern California wildfires will

OTHER CONTINGENCIES AND COMMITM

OTHER CONTINGENCIES AND COMMITMENTS	6 Months Ended
	Jun. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
OTHER CONTINGENCIES AND COMMITMENTS	WILDFIRE-RELATED CONTINGENCIES PG&E Corporation and the Utility have significant contingencies arising from their operations, including contingencies related to wildfires. A provision for a loss contingency is recorded when it is both probable that a liability has been incurred and the amount of the liability can be reasonably estimated. PG&E Corporation and the Utility evaluate which potential liabilities are probable and the related range of reasonably estimated losses and record a charge that reflects their best estimate or the lower end of the range, if there is no better estimate. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of losses is estimable, often involves a series of complex judgments about future events. Loss contingencies are reviewed quarterly, and estimates are adjusted to reflect the impact of all known information, such as negotiations, discovery, settlements and payments, rulings, advice of legal counsel, and other information and events pertaining to a particular matter. PG&E Corporation’s and the Utility’s provision for loss and expense excludes anticipated legal costs, which are expensed as incurred. PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows may be materially affected by the outcome of the following matters. 2015 Butte Fire In September 2015, a wildfire (the “2015 Butte fire”) ignited and spread in Amador and Calaveras Counties in Northern California. Cal Fire concluded that the 2015 Butte fire was caused when a gray pine tree contacted the Utility’s electric line, which ignited portions of the tree, and determined that the failure by the Utility and/or its vegetation management contractors, ACRT Inc. and Trees, Inc., to identify certain potential hazards during its vegetation management program ultimately led to the failure of the tree. See “Pre-Petition Wildfire-Related Claims and Discharge Upon Plan Effective Date” and “District Attorney’s Office Investigations” below for more information on the 2015 Butte fire. 2018 Camp Fire and 2017 Northern California Wildfires Background According to Cal Fire, on November 8, 2018 at approximately 6:33 a.m., a wildfire began near the city of Paradise, Butte County, California (the “2018 Camp fire”), which is located in the Utility’s service territory. Cal Fire’s Camp Fire Incident Information Website as of November 15, 2019 (the “Cal Fire website”) indicated that the 2018 Camp fire consumed 153,336 acres. On the Cal Fire website, Cal Fire reported 85 fatalities and the destruction of 18,804 structures resulting from the 2018 Camp fire. Beginning on October 8, 2017, multiple wildfires spread through Northern California, including Napa, Sonoma, Butte, Humboldt, Mendocino, Lake, Nevada, and Yuba Counties, as well as in the area surrounding Yuba City (the “2017 Northern California wildfires”). According to the Cal Fire California Statewide Fire Summary dated October 30, 2017, at the peak of the 2017 Northern California wildfires, there were 21 major fires that, in total, burned over 245,000 acres and destroyed an estimated 8,900 structures. The 2017 Northern California wildfires resulted in 44 fatalities. As described below under the heading “Restructuring Support Agreement with the TCC,” on December 6, 2019, PG&E Corporation and the Utility entered into a RSA with the TCC, the Consenting Fire Claimant Professionals and the Shareholder Proponents to potentially resolve all wildfire-related claims relating to the 2017 Northern California wildfires and the 2018 Camp fire (other than subrogated insurance claims and Public Entity Wildfire Claims) through the Chapter 11 process. On December 19, 2019, the Bankruptcy Court entered an order approving the TCC RSA. As described below under the heading “Restructuring Support Agreement with Holders of Subrogation Claims,” on September 22, 2019, PG&E Corporation and the Utility entered into a RSA with certain holders of insurance subrogation claims to potentially resolve all insurance subrogation claims relating to the 2017 Northern California wildfires and the 2018 Camp fire through the Chapter 11 process. On December 19, 2019, the Bankruptcy Court entered an order approving the Subrogation RSA. As described below under the heading “Plan Support Agreements with Public Entities,” on June 18, 2019, PG&E Corporation and the Utility entered into agreements with certain government entities to potentially resolve their wildfire-related claims through the Chapter 11 process. The PSAs do not require Bankruptcy Court approval to be effective; however, Bankruptcy Court approval of the Plan that incorporates the terms of the PSAs was required. The Bankruptcy Court confirmed the Plan on June 20, 2020. On April 21, 2020, the parties announced that settlement agreements had been reached with certain Federal agencies (including FEMA and the United States Small Business Administration (the “SBA”)) and certain State agencies (including Cal OES and Cal Fire) regarding their claims filed against PG&E Corporation or the Utility in the Chapter 11 Cases which constitute “Fire Claims” (as defined in the Plan). Pursuant to the terms of the settlement agreements: • the Fire Claims of FEMA and the SBA were allowed at $1 billion, channeled to the Fire Victim Trust, and fully subordinated and made junior in right of payment to the prior payment in full of all other Fire Victim Claims from the Fire Victim Trust; • $117 million will be paid to the DOJ in full and final satisfaction and discharge of the Fire Claims of certain other Federal agencies and payable solely from the proceeds of the “Assigned Rights and Causes of Action” (as defined in the Plan), after the payment of professional fees and costs incurred in connection with the prosecution of such Assigned Rights and Causes of Action; • Cal OES’s Fire Claims were withdrawn with prejudice; • Cal Fire’s Fire Claims were allowed at $115.3 million (the “Cal Fire Settlement Amount”), payable over a period of years by the Fire Victim Trust, with the first $70 million payable solely and exclusively from any cash interest earned on the cash holdings of the Fire Victim Trust after the Effective Date and the remaining $45.3 million payable solely and exclusively from such cash interest less the expenses of administering the Fire Victim Trust in such years; • the Fire Claims of certain other State agencies were allowed at $89 million, payable by the Fire Victim Trust over a period of years, with the first $60 million payable solely and exclusively from proceeds of the monetization of the PG&E Corporation common stock in excess of $6.75 billion in accordance with an agreed-upon formula and available cash interest after expenses and after the Cal Fire Settlement Amount has been paid in full, and the balance payable solely and exclusively from such monetization proceeds and interest earned on the cash holdings of the Fire Victim Trust (less expenses of administering the Fire Victim Trust); and • the holders of the above claims that are being settled and channeled to the Fire Victim Trust, consistent with the Plan, have no right of recovery from PG&E Corporation or the Utility. Consistent with the Plan and the agreements, the obligations of payment relating to the agreements are solely the responsibility of the Fire Victim Trust, and PG&E Corporation and the Utility will have no further obligations with respect to the claims that are the subject of the agreements. PG&E Corporation and the Utility filed a motion seeking Bankruptcy Court approval of the settlement agreements on April 26, 2020, and the Bankruptcy Court approved the settlement agreements on May 18, 2020. Pre-petition Wildfire-Related Claims and Discharge Upon Plan Effective Date Pre-petition wildfire-related claims on the Condensed Consolidated Financial Statements include amounts associated with the 2018 Camp fire, the 2017 Northern California wildfires, and the 2015 Butte fire. At June 30, 2020 and December 31, 2019, the Utility’s Consolidated Balance Sheets include estimated liabilities in respect of total wildfire-related claims of $25.5 billion. The aggregate liability of $25.5 billion for claims in connection with the 2018 Camp fire, the 2017 Northern California wildfires, and the 2015 Butte fire is comprised of (i) $11 billion for subrogated insurance claimholders pursuant to the Subrogation RSA, plus (ii) $47.5 million for expected professional fees for professionals retained by subrogated insurance claimholders to be reimbursed pursuant to the Subrogation RSA, plus (iii) $1 billion for the Supporting Public Entities with respect to their Public Entity Wildfire Claims pursuant to the PSAs, plus (iv) $13.5 billion for all other wildfire-related claims, including individual wildfire claimholders (including those with uninsured and underinsured property losses) and clean-up and fire suppression costs, pursuant to the TCC RSA. The aggregate liability of $25.5 billion for claims in connection with the 2018 Camp fire, the 2017 Northern California wildfires and the 2015 Butte fire corresponded PG&E Corporation’s and the Utility’s best estimate of probable losses. On July 1, 2020, pursuant to the Plan, PG&E Corporation and the Utility funded the Fire Victim Trust with $5.4 billion in cash (with an additional $1.35 billion to be funded on a deferred basis), 477.0 million shares of common stock of PG&E Corporation (representing 22.19% of the outstanding common stock of PG&E Corporation as of the Effective Date (subject to potential adjustments)), plus the assignment of certain rights and causes of action. In accordance with the Plan and the Confirmation Order, as a result of such funding, all Fire Victim Claims (as defined in the Plan) have been satisfied, released and discharged and channeled to the Fire Victim Trust with no recourse to PG&E Corporation or the Utility. Accordingly, $12.15 billion of the $13.5 billion liability as of June 30, 2020 will be extinguished in the third quarter of 2020, and the remaining $1.35 billion will be paid out under the terms of the Tax Benefits Payment Agreement, as described in Note 2 under the heading “Chapter 11 Claims Process.” On July 1, 2020, PG&E Corporation and the Utility funded the Subrogation Wildfire Trust for the benefit of insurance subrogation claimants in the amount of $11.0 billion in cash and paid approximately $43 million in respect of professional fees of such claimants, for a total of approximately $52 million for claimants’ professional fees. Such amount was initially funded into escrow and later paid to the Subrogation Wildfire Trust. In accordance with the Plan and the Confirmation Order, as a result of such funding, all insurance subrogation claims have been satisfied, released and discharged and channeled to the Subrogation Wildfire Trust with no recourse to PG&E Corporation or the Utility. Accordingly, the $11.0 billion liability accrual for subrogated insurance claims and $47.5 million liability for professional fees will be extinguished in the third quarter of 2020. On July 1, 2020, PG&E Corporation and the Utility paid $1.0 billion in cash to the Settling Public Entities and established a segregated fund in the amount of $10 million to be used to reimburse the Settling Public Entities for any and all legal fees and costs associated with the defense or resolution of any third party claims against the Settling Public Entities. In accordance with the Plan and the Confirmation Order, as a result of such payments, the Public Entity Wildfire Claims have been satisfied, released and discharged. Accordingly, the $1.0 billion liability for Public Entity Wildfire Claims will be extinguished in the third quarter of 2020. In addition, during the three and six months ended June 30, 2020, the Utility incurred legal and other costs of $24 million and $58 million, respectively, related to the 2018 Camp fire, the 2017 Northern California wildfires and the 2015 Butte fire, as compared to $26 million and $73 million, respectively, during the same periods in 2019. During the three and six months ended June 30, 2020, the Utility incurred legal and other costs of $2 million related to the 2019 Kincade fire. Plan Support Agreements with Public Entities On June 18, 2019, PG&E Corporation and the Utility entered into PSAs with certain local public entities (collectively, the “Supporting Public Entities”) providing for an aggregate of $1.0 billion to be paid by PG&E Corporation and the Utility to such public entities pursuant to the Plan in order to settle and discharge such public entities’ claims against PG&E Corporation and the Utility relating to the 2018 Camp fire, 2017 Northern California wildfires and 2015 Butte fire (collectively, “Public Entity Wildfire Claims”). The PSAs also provide that, following the Effective Date, PG&E Corporation and the Utility will create and promptly fund $10.0 million to a segregated fund (the “Public Entity Segregated Defense Fund”) to be used by the Supporting Public Entities collectively in connection with the defense or resolution of claims against the Supporting Public Entities by third parties relating to the wildfires noted above (“Third Party Claims”). These elements were incorporated into the Plan which was approved by the Bankruptcy Court in the Confirmation Order. As described in “Chapter 11 Claims Process” above, the actions required by each PSA were taken on or around the Effective Date. Restructuring Support Agreement with Holders of Subrogation Claims On September 22, 2019, PG&E Corporation and the Utility entered into the Subrogation RSA. The Subrogation RSA provides for an aggregate amount of $11.0 billion (the “Aggregate Subrogation Recovery”) to be paid by PG&E Corporation and the Utility pursuant to the Plan in order to settle the Subrogation Claims, upon the terms and conditions set forth in the Subrogation RSA. Under the Subrogation RSA, PG&E Corporation and the Utility have also agreed to reimburse the holders of Subrogation Claims for professional fees of up to $55 million, upon the terms and conditions set forth in the Subrogation RSA. As described above under the heading “Pre-petition Wildfire-Related Claims and Discharge Upon Plan Effective Date,” the payments described in the Subrogation RSA were made on the Effective Date. Restructuring Support Agreement with the TCC On December 6, 2019, PG&E Corporation and the Utility entered into the TCC RSA. The TCC RSA provides for, among other things, a combination of cash and common stock of the reorganized PG&E Corporation to be provided by PG&E Corporation and the Utility pursuant to the Plan (together with certain additional rights, the “Aggregate Fire Victim Consideration”) in order to settle and discharge the Fire Victim Claims, upon the terms and conditions set forth in the TCC RSA and the Plan. The Aggregate Fire Victim Consideration to be funded into the Fire Victim Trust to be established pursuant to the Plan for the benefit of holders of the Fire Victim Claims will consist of (a) $5.4 billion in cash to be contributed on the Effective Date of the Plan, (b) $1.35 billion in cash consisting of (i) $650 million to be paid in cash on or before January 15, 2021 and (ii) the remaining balance of $1.35 billion to be paid in cash on or before January 15, 2022, in each case pursuant to the terms of a tax benefit payment agreement to be entered into between the Fire Victim Trust and the reorganized Utility, and (c) an amount of common stock of the reorganized PG&E Corporation valued at 14.9 times Normalized Estimated Net Income (as defined in the TCC RSA), except that the Fire Victim Trust’s share ownership of the reorganized PG&E Corporation will not be less than 20.9% based on the number of fully diluted shares of the reorganized PG&E Corporation outstanding as of the Effective Date of the Plan, assuming the Utility’s allowed ROE as of the date of the TCC RSA. Under certain circumstances, including certain change of control transactions and in connection with the monetization of certain tax benefits related to the payment of wildfire-related claims, the payments described in clause (b) will be accelerated and payable upon an earlier date. The Aggregate Fire Victim Consideration also includes (1) the assignment by PG&E Corporation and the Utility to the Fire Victim Trust of certain rights and causes of action related to the 2015 Butte fire, the 2017 Northern California wildfires and the 2018 Camp fire (together, the “Fires”) that PG&E Corporation and the Utility may have against certain third parties and (2) the assignment of rights under the 2015 insurance policies to resolve any claims related to the Fires in those policy years, other than the rights of PG&E Corporation and the Utility to be reimbursed under the 2015 insurance policies for claims submitted to and paid by PG&E Corporation and the Utility prior to the Petition Date to resolve any claims related to the Fires in those policy years. On June 11, 2020, PG&E Corporation and the Utility and the TCC agreed that the percentage ownership of the Fire Victim Trust will be 22.19% of the outstanding shares of the PG&E Corporation on the Effective Date. Pursuant to further discussions with claimants relating to the Ghost Ship fire, certain provisions of the TCC RSA were superseded by the terms of the Plan, and accordingly the above description of the TCC RSA has been revised to reflect the fact that claims arising out of the Ghost Ship fire will be resolved separately from the TCC RSA. As described above under the heading “Pre-petition Wildfire-Related Claims and Discharge Upon Plan Effective Date,” the funding to be made pursuant to the TCC RSA and the Plan were made on the Effective Date. 2019 Kincade Fire According to Cal Fire, on October 23, 2019 at approximately 9:27 p.m., a wildfire began northeast of Geyserville in Sonoma County, California (the “2019 Kincade fire”), located in the service territory of the Utility. The Cal Fire Kincade Fire Incident Update dated November 20, 2019, 11:02 a.m. Pacific Time (the “incident update”) indicated that the 2019 Kincade fire had consumed 77,758 acres. In the incident update, Cal Fire reported no fatalities and four first responder injuries. The incident update also indicates the following: structures destroyed, 374 (consisting of 174 residential structures, 11 commercial structures and 189 other structures); and structures damaged, 60 (consisting of 35 residential structures, one commercial structure and 24 other structures). In connection with the 2019 Kincade fire, state and local officials issued numerous mandatory evacuation orders and evacuation warnings at various times for certain areas of the region. 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 October 23, 2019, by 3:00 p.m. Pacific Time, the Utility had conducted a PSPS event and turned off the power to approximately 27,837 customers in Sonoma County, including Geyserville and the surrounding area. As part of the PSPS, the Utility’s distribution lines in these areas were deenergized. Following the Utility’s established and CPUC-approved PSPS protocols and procedures, transmission lines in these areas remained energized. The Utility has submitted electric incident reports to the CPUC indicating that: • at approximately 9:19 p.m. Pacific Time on October 23, 2019, the Utility became aware of a transmission level outage on the Geysers #9 Lakeville 230 kV line when the line relayed and did not reclose; • various generating facilities on the Geysers #9 Lakeville 230kV line detected the disturbance and separated at approximately the same time; • at approximately 9:21 p.m. Pacific Time, the PG&E Grid Control Center received a report that a fire had started in an area near transmission tower 001/006; • at approximately 7:30 a.m. Pacific Time on October 24, 2019, a responding Utility troubleman patrolling the Geysers #9 Lakeville 230 kV line observed that Cal Fire had taped off the area around the base of transmission tower 001/006 in the area of the 2019 Kincade fire; and • on site Cal Fire personnel brought to the troubleman’s attention what appeared to be a broken jumper on the same tower. On July 16, 2020, Cal Fire issued a press release addressing the cause of the 2019 Kincade fire. Cal Fire has determined that “the Kincade Fire was caused by electrical transmission lines owned and operated by Pacific Gas and Electric (PG&E) located northeast of Geyserville. Tinder dry vegetation and strong winds combined with low humidity and warm temperatures contributed to extreme rates of fire spread.” Cal Fire also indicated that its investigative report has been forwarded to the Sonoma County District Attorney’s Office, which is reviewing the matter. PG&E Corporation and the Utility are also conducting their own investigation into the cause of the 2019 Kincade fire. This investigation is preliminary, and PG&E Corporation and the Utility do not have access to all of the evidence in the possession of Cal Fire or other third parties. Potential liabilities related to the Kincade Fire depend on various factors, including but not limited to the cause of the fire, contributing causes of the fire (including alternative potential origins, weather- and climate-related issues), 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, 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 or fines that may be imposed by governmental entities. If the Utility’s facilities, such as its electric distribution and transmission lines, are judicially determined to be the substantial cause of the Kincade fire, 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 from their customers. 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. (See “Loss Recoveries – Regulatory Recovery” below for further information regarding potential cost recovery related to the wildfires.) In light of the current state of the law concerning inverse condemnation and the information currently available to PG&E Corporation and the Utility as of the date of this filing, including the information contained in the electric incident reports, Cal Fire’s determination of the cause, and other 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 of at least $600 million in connection with the 2019 Kincade fire (before available insurance). This amount corresponds to the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimable range of losses and is subject to change based on additional information. The $600 million estimate does not include, among other things, (i) any amounts for potential penalties or fines that may be imposed by governmental entities on PG&E Corporation or the Utility, (ii) any punitive damages, (iii) any amounts in respect of compensation claims by Federal, state, county and local government entities or agencies other than state fire suppression costs, (iv) evacuation costs or (v) any other amounts that are not reasonably estimable. PG&E Corporation and the Utility currently believe that it is reasonably possible that the amount of loss could be greater than $600 million (before available insurance) but are unable to reasonably estimate the additional loss and the upper end of the range because, as described above, there are a number of unknown facts and legal considerations that may impact the amount of any potential liability, including the total scope and nature of claims that may be asserted against PG&E Corporation and the Utility. If the liability for the 2019 Kincade fire were to exceed $1.0 billion, it is possible the Utility would be eligible to make a claim to the Wildfire Fund under AB 1054 for such excess amount, subject to the 40% limitation on 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 Cal Fire’s possession, evidence from or held by other parties, claims that have not yet been submitted, and additional information about the nature and extent of potential damages. The process for estimating losses associated with potential claims related to the 2019 Kincade fire requires management to exercise significant judgment based on a number of assumptions and subjective factors, including the factors identified above and estimates based on currently available information and prior experience with wildfires. As more information becomes available, management estimates and assumptions regarding the potential financial impact of the 2019 Kincade fire may change. The Utility has liability insurance from various insurers, which provides coverage for third-party liability attributable to the Kincade fire in an aggregate amount of $430 million. The Utility records insurance recoveries when it is deemed probable that recovery will occur, and the Utility can reasonably estimate the amount or its range. As of June 30, 2020, the Utility has recorded an insurance receivable for the full amount of the $430 million. While the Utility plans to seek recovery of all insured losses, it is unable to predict the ultimate amount and timing of such insurance recoveries. PG&E Corporation and the Utility have received and are responding to data requests from the SED relating to the Kincade fire. Various other entities, including law enforcement agencies, may also be investigating the fire. It is uncertain when the investigations will be complete. As of July 24, 2020, PG&E Corporation and the Utility are aware of three complaints on behalf of approximately 142 plaintiffs related to the 2019 Kincade fire and expects that they may receive further such complaints. The complaints were filed in the California Superior Court for the County of Sonoma and include claims based on multiple theories of liability, including inverse condemnation, negligence, violations of the Public Utilities Code, violations of the Health & Safety Code, premises liability, trespass, public nuisance and private nuisance. The plaintiffs in each action principally assert that PG&E Corporation’s and the Utility’s alleged failure to properly maintain, inspect and de-energize their transmission lines was the cause of the 2019 Kincade fire. The plaintiffs seek damages that include property damage, economic loss, punitive damages, exemplary damages, attorneys’ fees and other damages. In addition to claims for property damage, business interruption, interest and attorneys’ fees, 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, including if the Utility were found to have been negligent. Loss Recoveries PG&E Corporation and the Utility have insurance coverage for liabilities, including wildfire. Additionally, there are several mechanisms that allow for recovery of costs from customers. Potential for recovery is described below. Failure to obtain a substantial or full recovery of costs related to the 2018 Camp fire and 2017 Northern California wildfires or any conclusion that such recovery is no longer probable could have a material effect on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows. In addition, the inability to recover costs in a timely manner could have a material effect on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows. Insurance Insurance Coverage PG&E Corporation and the Utility have liability insurance coverage for wildfire events in an amount of $430 million (subject to an initial self-insured retention of $10 million per occurrence) for the period from August 1, 2019 through July 31, 2020, and approximately $1 billion in liability insurance coverage for non-wildfire events (subject to an initial self-insured retention of $10 million per occurrence), comprised of $520 million for the period from August 1, 2019 through July 31, 2020 and $480 million for the period from September 3, 2019 through September 2, 2020. PG&E Corporation’s and the Utility’s cost of obtaining this wildfire and non-wildfire insurance coverage in place for the period of August 1, 2019 through September 2, 2020 is approximately $212 million. In July 2020, the Utility renewed its liability insurance coverage for wildfire events in the amount of $757.5 million (subject to an initial self-insured retention of $60 million), comprised of $715 million for the period of August 1, 2020 to July 31, 2021 and $42.5 million in reinsurance for the period of July 1, 2020 through June 30, 2021. In addition, the Utility renewed its liability insurance coverage for non-wildfire events in the amount of $700 million (subject to an initial self-insured retention of $10 million) for the period from August 1, 2020 through July 31, 2021. PG&E Corporation and the Utility’s cost of obtaining this wildfire and non-wildfire coverage is approximately $749 million. PG&E Corporation and the Utility continue to pursue additional insurance coverage for the period from August 1, 2020 through July 31, 2021. Various coverage limitations applicable to different insurance layers could result in material uninsured costs in the future depending on the amount and type of damages resulting from covered events. The Utility’s 2020 GRC settlement agreement, currently pending before the Commission, includes a new two-way balancing account that, if approved, would allow the Utility to recover in rates its actual insurance premium costs for up to $1.4 billion in coverage. The Utility is unable to predict the timing and outcome of the 2020 GRC proceeding. The Utility will not be able to obtain any recovery from the Wildfire Fund for wildfire-related losses in any calendar year that do not exceed the greater of $1.0 billion in the aggregate and the amount of insurance coverage required under AB 1054. Insurance Receivable PG&E Corporation and the Utility record a receivable for insurance recoveries when it is deemed probable that recovery of a recorded loss will occur. Through June 30, 2020, PG&E Corporation and the Utility recorded $1.38 billion for probable insurance recoveries in connection with the 2018 Camp fire, $843 million for probable insurance recoveries in connection with the 2017 Northern California wildfires, and $430 million for probable insurance recoveries in connection with the 2019 Kincade fire. These amounts reflect an assumption that the cause of each fire is deemed to be a separate occurrence under the insurance policies. PG&E Corporation and the Utility intend to seek full recovery for all insured losses. If PG&E Corporation and the Utility are unable to recover the full amount of their insurance, PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows could be materially affected. Even if PG&E Corporation and the Utility were to recover the full amount of their insurance, PG&E Corporation and the Utility expect their losses in connection with the 2018 Camp fire and the 2017 Northern California wildfires will

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	6 Months Ended
	Jun. 30, 2020
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS The Plan became effective and PG&E Corporation and the Utility emerged from Chapter 11 on July 1, 2020. Several transactions related to PG&E Corporation’s and the Utility’s emergence from Chapter 11 occurred after June 30, 2020, including on July 1, 2020 and thereafter. For disclosure of such subsequent events, please see the Notes to these Condensed Consolidated Financial Statements above. On July 27, 2020, Elliott Management Corporation, a Consenting Noteholder, filed a motion with the Bankruptcy Court asserting an approximately $250 million administrative claim against PG&E Corporation and the Utility, alleging that PG&E Corporation and the Utility breached the Noteholder RSA by failing to use their best efforts to cause Backstop Parties to transfer up to $2.0 billion of Backstop Commitments to certain of the Consenting Noteholders. Objections to the motion are due on August 11, 2020, and a hearing on the motion is scheduled for August 25, 2020. PG&E Corporation and the Utility are unable to predict the timing and outcome of this proceeding.

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
Basis of Presentation	This quarterly report on Form 10-Q is a combined report of PG&E Corporation and the Utility.  PG&E Corporation’s Condensed Consolidated Financial Statements include the accounts of PG&E Corporation, the Utility, and other wholly owned and controlled subsidiaries.  The Utility’s Condensed Consolidated Financial Statements include the accounts of the Utility and its wholly owned and controlled subsidiaries.  All intercompany transactions have been eliminated in consolidation.  The Notes to the Condensed Consolidated Financial Statements apply to both PG&E Corporation and the Utility.  PG&E Corporation and the Utility assess financial performance and allocate resources on a consolidated basis (i.e., the companies operate in one segment).The accompanying Condensed Consolidated Financial Statements have been prepared in conformity with GAAP and in accordance with the interim period reporting requirements of Form 10-Q and reflect all adjustments that management believes are necessary for the fair presentation of PG&E Corporation’s and the Utility’s financial condition, results of operations, and cash flows for the periods presented.  The information at December 31, 2019 in the Condensed Consolidated Balance Sheets included in this quarterly report was derived from the audited Consolidated Balance Sheets in Item 8 of the 2019 Form 10-K.  This quarterly report should be read in conjunction with the 2019 Form 10-K.
Use of Estimates and Assumptions	The preparation of financial statements in conformity with GAAP requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Some of the more significant estimates and assumptions relate to the Utility’s regulatory assets and liabilities, wildfire-related liabilities, legal and regulatory contingencies, the Wildfire Fund, environmental remediation liabilities, AROs, insurance receivables, and pension and other post-retirement benefit plan obligations. Management believes that its estimates and assumptions reflected in the Condensed Consolidated Financial Statements are appropriate and reasonable. A change in management’s estimates or assumptions could result in an adjustment that would have a material impact on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows during the period in which such change occurred
Variable Interest Entities	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. 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 has a controlling interest or was the primary beneficiary of any of these VIEs at June 30, 2020, the Utility assessed whether it absorbs any of the VIE’s expected losses or receives any portion of the VIE’s expected residual returns under the terms of the power purchase agreement, analyzed the variability in the VIE’s gross margin, and considered whether it had any decision-making rights associated with the activities that are most significant to the VIE’s performance, such as dispatch rights and operating and maintenance activities. The Utility’s financial obligation is limited to the amount the Utility pays for delivered electricity and capacity. The Utility did not have any decision-making rights associated with any of the activities that are most significant to the economic performance of any of these VIEs. Since the Utility was not the primary beneficiary of any of these VIEs at June 30, 2020, it did not consolidate any of them.
Pension and Other Post-Retirement Benefits	PG&E Corporation and the Utility sponsor a non-contributory defined benefit pension plan and cash balance plan.  Both plans are included in “Pension Benefits” below.  Post-retirement medical and life insurance plans are included in “Other Benefits” below.
Pension and Other Postretirement Plans	Non-service costs are reflected in Other income, net on the Condensed Consolidated Statements of Income. Service costs are reflected in Operating and maintenance on the Condensed Consolidated Statements of Income.
Revenue Recognition	Revenue Recognition Revenue from Contracts with Customers The Utility recognizes revenues when electricity and natural gas services are delivered. The Utility records unbilled revenues for the estimated amount of energy delivered to customers but not yet billed at the end of the period. Unbilled revenues are included in accounts receivable on the Condensed Consolidated Balance Sheets. Rates charged to customers are based on CPUC and FERC authorized revenue requirements. Revenues can vary significantly from period to period because of seasonality, weather, and customer usage patterns. Regulatory Balancing Account Revenue The CPUC authorizes most of the Utility’s revenues in the Utility’s GRC and GT&S rate cases, which generally occur every three or four years. The Utility’s ability to recover revenue requirements authorized by the CPUC in these rate cases is independent, or “decoupled,” from the volume of the Utility’s sales of electricity and natural gas services. The Utility recognizes revenues that have been authorized for rate recovery, are objectively determinable and probable of recovery, and are expected to be collected within 24 months. Generally, electric and natural gas operating revenue is recognized ratably over the year. The Utility records a balancing account asset or liability for differences between customer billings and authorized revenue requirements that are probable of recovery or refund. The CPUC also has authorized the Utility to collect additional revenue requirements to recover costs that the Utility has been authorized 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.
Recently Adopted Accounting Standards and Accounting Standards Issued But Not Yet Adopted	Recently Adopted Accounting Standards Intangibles—Goodwill and Other In August 2018, the FASB issued ASU No. 2018-15, Intangibles – Goodwill and Other – Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement that is a Service Contract. PG&E Corporation and the Utility adopted the ASU on January 1, 2020. The adoption of this ASU did not have a material impact on the Condensed Consolidated Financial Statements and related disclosures. Financial Instruments—Credit Losses In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments – Credit Losses (Topic 326), which provides a model, known as the current expected credit loss model, to estimate the expected lifetime credit loss on financial assets, including trade and other receivables, rather than incurred losses over the remaining life of most financial assets measured at amortized cost. The guidance also requires use of an allowance to record estimated credit losses on available-for-sale debt securities. PG&E Corporation and the Utility adopted the ASU on January 1, 2020. PG&E Corporation and the Utility have three categories of financial assets in scope, each with their own associated credit risks. In applying the new guidance, PG&E Corporation and the Utility have incorporated forward-looking data in its estimate of credit loss as follows. Trade receivables are represented by customer accounts receivable and have credit exposure risk related to California unemployment rates. 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. Lastly, available-for-sale debt securities requires each company to determine if a decline in fair value is below amortized costs basis, or, impaired. Furthermore, if an impairment exists on available-for-sale debt securities, PG&E Corporation and the Utility will examine if there is an intent to sell, if it is more likely than not a requirement to sell prior to recovery, and if a portion of the unrealized loss is a result of credit loss. There was no material impact to PG&E Corporation or the Utility’s Condensed Consolidated Financial Statements resulting from the adoption of this ASU. During the three months ended June 30, 2020, expected credit losses of $44 million were recorded in Operating and maintenance expense on the Condensed Consolidated Statements of Income. Reference Rate Reform In March 2020, the FASB issued ASU No. 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting , which provides optional guidance for a limited period of time to ease the potential burden in accounting for (or recognizing the effects of) reference rate reform on financial reporting. PG&E Corporation and the Utility adopted this ASU on April 1, 2020 and elected the optional amendments for contract modifications prospectively. There was no material impact to PG&E Corporation or the Utility’s Condensed Consolidated Financial Statements resulting from the adoption of this ASU. Accounting Standards Issued But Not Yet Adopted Defined Benefit Plans In August 2018, the FASB issued ASU No. 2018-14, Fair Value Measurement (Subtopic 715-20): Disclosure Framework-Changes to the Disclosure Requirements for Defined Benefit Plans , which amends the existing guidance relating to the disclosure requirements for Defined Benefit Plans. PG&E Corporation and the Utility plan to adopt this guidance in the fourth quarter of 2020. PG&E Corporation and the Utility are currently evaluating the impact the guidance will have on their Condensed Consolidated Financial Statements and related disclosures. Income Taxes In December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes , which amends the existing guidance to reduce complexity relating to Income Tax disclosures. PG&E Corporation and the Utility plan to adopt this guidance in the first quarter of 2021. PG&E Corporation and the Utility does not anticipate the guidance will have a material impact on their Condensed Consolidated Financial Statements and related disclosures.
Earnings Per Share	PG&E Corporation’s basic EPS is calculated by dividing the income available for common shareholders by the weighted average number of common shares outstanding.  PG&E Corporation applies the treasury stock method of reflecting the dilutive effect of outstanding share-based compensation in the calculation of diluted EPS.
Use of Derivative Instruments	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 customer 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. By order dated April 8, 2019, the Bankruptcy Court authorized the Utility to continue these programs in the ordinary course of business in a manner consistent with its pre-petition practices. Derivatives are presented in the Utility’s Condensed Consolidated Balance Sheets recorded at fair value and on a net basis in accordance with master netting arrangements for each counterparty. The fair value of derivative instruments is further offset by cash collateral paid or received where the right of offset and the intention to offset exist. Price risk management activities that meet the definition of derivatives are recorded at fair value on the Condensed Consolidated Balance Sheets. These instruments are not held for speculative purposes and are subject to certain regulatory requirements. The Utility expects to fully recover in rates all costs related to derivatives under the applicable ratemaking mechanism in place as long as the Utility’s price risk management activities are carried out in accordance with CPUC directives. Therefore, all unrealized gains and losses associated with the change in fair value of these derivatives are deferred and recorded within the Utility’s regulatory assets and liabilities on the Condensed Consolidated Balance Sheets. Net realized gains or losses on commodity derivatives are recorded in the cost of electricity or the cost of natural gas with corresponding increases or decreases to regulatory balancing accounts for recovery from or refund to customers. The Utility elects the normal purchase and sale exception for eligible derivatives. Eligible derivatives are those that require physical delivery in quantities that are expected to be used by the Utility over a reasonable period in the normal course of business, and do not contain pricing provisions unrelated to the commodity delivered. These items are not reflected in the Condensed Consolidated Balance Sheets at fair value.
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.
Valuation Techniques	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 three and six months ended June 30, 2020 and 2019. Trust Assets Assets Measured at Fair Value In general, investments held in the trusts are exposed to various risks, such as interest rate, credit, and market volatility risks. Nuclear decommissioning trust assets and other trust assets are composed primarily of equity and fixed-income securities and also include short-term investments that are money market funds valued as Level 1. Global equity securities primarily include investments in common stock that are valued based on quoted prices in active markets and are classified as Level 1. Fixed-income securities are primarily composed of U.S. government and agency securities, municipal securities, and other fixed-income securities, including corporate debt securities. U.S. government and agency securities primarily consist of U.S. Treasury securities that are classified as Level 1 because the fair value is determined by observable market prices in active markets. A market approach is generally used to estimate the fair value of fixed-income securities classified as Level 2 using evaluated pricing data such as broker quotes, for similar securities adjusted for observable differences. Significant inputs used in the valuation model generally include benchmark yield curves and issuer spreads. The external credit ratings, coupon rate, and maturity of each security are considered in the valuation model, as applicable. Assets Measured at NAV Using Practical Expedient Investments in the nuclear decommissioning trusts and the long-term disability trust that are measured at fair value using the NAV per share practical expedient have not been classified in the fair value hierarchy tables above. The fair value amounts are included in the tables above in order to reconcile to the amounts presented in the Condensed Consolidated Balance Sheets. These investments include commingled funds that are composed of equity securities traded publicly on exchanges as well as fixed-income securities that are composed primarily of U.S. government securities 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. Market and credit risk management utilizes models to derive pricing inputs for the valuation of the Utility’s Level 3 instruments using pricing inputs from brokers and historical data.
Contingencies and Commitments	PG&E Corporation and the Utility have significant contingencies arising from their operations, including contingencies related to enforcement and litigation matters and environmental remediation. A provision for a loss contingency is recorded when it is both probable that a loss has been incurred and the amount of the loss can be reasonably estimated. PG&E Corporation and the Utility evaluate the range of reasonably estimated losses and record a provision based on the lower end of the range, unless an amount within the range is a better estimate than any other amount. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of loss is estimable, often involves a series of complex judgments about future events. Loss contingencies are reviewed quarterly and estimates are adjusted to reflect the impact of all known information, such as negotiations, discovery, settlements and payments, rulings, penalties related to regulatory compliance, advice of legal counsel, and other information and events pertaining to a particular matter. PG&E Corporation’s and the Utility’s policy is to exclude anticipated legal costs from the provision for loss and expense these costs as incurred. The Utility also has substantial financial commitments in connection with agreements entered into to support its operating activities. See “Purchase Commitments” below. 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.

BANKRUPTCY FILING (Tables)

BANKRUPTCY FILING (Tables)	6 Months Ended
	Jun. 30, 2020
Reorganizations [Abstract]
Schedule of Liabilities Subject to Compromise	Liabilities subject to compromise as of December 31, 2019 which were settled or reclassified during the six months ended June 30, 2020 consist of the following: (in millions) Utility PG&E Corporation (1) December 31, 2019 Change in Estimated Allowed Claim 2020 (2) Cash Reclassified (3) Utility PG&E Corporation (1) June 30, 2020 Financing debt $ 22,450 $ 666 $ 23,116 $ 351 $ — $ (23,467) $ — $ — $ — Wildfire-related claims 25,548 — 25,548 18 (23) (25,543) — — — Trade creditors (4) 1,183 5 1,188 6 (14) (1,180) — — — Non-qualified benefit plan 20 137 157 — — (157) — — — 2001 bankruptcy disputed claims 234 — 234 4 — (238) — — — Customer deposits & advances 71 — 71 12 — (83) — — — Other 230 2 232 59 — (291) — — — Total Liabilities Subject to Compromise $ 49,736 $ 810 $ 50,546 $ 450 $ (37) $ (50,959) $ — $ — $ — (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) Change in estimated allowed claim amounts are primarily due to interest accruals with the exception of the “wildfire-related claims”, “customer deposits & advances”, and “other” line items which are mainly due to the adjustment to recorded liabilities. (3) Amounts reclassified included $8.6 million to Accounts payable - other, $237.6 million to Disputed claims and customer refunds, $1,347.4 million to Interest payable, $21,425.7 million to Long-term debt, $300.0 million to Short-term borrowings, $450.0 million to Long-term debt, classified as current, $301.0 million to Other current liabilities, $97.9 million to Other non-current liabilities, $121.3 million to Pension and other post-retirement benefits, $1,126.9 million to Accounts payable - trade creditors, and $25,542.7 million to Wildfire-related claims on the Condensed Consolidated Balance Sheets. (4) As of July 24, 2020, $0.4 million and $290 million has been repaid by PG&E Corporation and the Utility, respectively.
Schedule of Debtor Reorganization Items	Reorganization items, net for the three and six months ended June 30, 2020 include the following: Three Months Ended June 30, 2020 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 1 $ — $ 1 Legal and other (2) 109 1,513 1,622 Interest income — — — Trustee fees (3) 1 — 1 Total reorganization items, net $ 111 $ 1,513 $ 1,624 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) Amount includes $1.5 billion in equity backstop premium expense and bridge loan facility fees. (3) PG&E Corporation and the Utility incurred $475,232 and $561,000, respectively, in fees to the U.S. Trustee in the three months ended June 30, 2020. Six Months Ended June 30, 2020 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 3 $ — $ 3 Legal and other (2) 205 1,597 1,802 Interest income (5) (2) (7) Trustee fees (3) 1 1 2 Total reorganization items, net $ 204 $ 1,596 $ 1,800 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) Amount includes $1.5 billion in equity backstop premium expense and bridge loan facility fees. (3) PG&E Corporation and the Utility incurred $724,232 and $824,930, respectively, in fees to the U.S. Trustee in the six months ended June 30, 2020. Reorganization items, net for the three months ended June 30, 2019 and from the Petition Date through June 30, 2019 include the following: Three Months Ended June 30, 2019 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ — $ — $ — Legal and other 75 1 76 Interest income (18) (3) (21) Trustee fees (2) — 1 1 Total reorganization items, net $ 57 $ (1) $ 56 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) PG&E Corporation and the Utility incurred $416,667 and $250,000, respectively, in fees to the U.S. Trustee in the three months ended June 30, 2019. Petition Date Through June 30, 2019 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 97 $ 17 $ 114 Legal and other 98 2 100 Interest income (27) (5) (32) Trustee fees (2) — 1 1 Total reorganization items, net $ 168 $ 15 $ 183 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) PG&E Corporation and the Utility incurred $416,667 and $250,000, respectively, in fees to the U.S. Trustee through June 30, 2019.

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
Components of Net Periodic Benefit Cost	The net periodic benefit costs reflected in PG&E Corporation’s Condensed Consolidated Financial Statements for the three and six months ended June 30, 2020 and 2019 were as follows: Pension Benefits Other Benefits Three Months Ended June 30, (in millions) 2020 2019 2020 2019 Service cost for benefits earned (1) $ 132 $ 111 $ 16 $ 14 Interest cost 179 190 15 19 Expected return on plan assets (261) (226) (35) (30) Amortization of prior service cost (2) (2) 4 3 Amortization of net actuarial loss 1 — (5) (1) Net periodic benefit cost 49 73 (5) 5 Regulatory account transfer (2) 34 10 — — Total $ 83 $ 83 $ (5) $ 5 (1) A portion of service costs are capitalized pursuant to GAAP. (2) The Utility recorded these amounts to a regulatory account since they are probable of recovery from, or refund to, customers in future rates. Pension Benefits Other Benefits Six Months Ended June 30, (in millions) 2020 2019 2020 2019 Service cost for benefits earned (1) $ 264 $ 222 $ 31 $ 28 Interest cost 357 379 31 38 Expected return on plan assets (522) (453) (69) (61) Amortization of prior service cost (3) (3) 7 7 Amortization of net actuarial loss 2 1 (10) (2) Net periodic benefit cost 98 146 (10) 10 Regulatory account transfer (2) 68 21 — — Total $ 166 $ 167 $ (10) $ 10 (1) A portion of service costs are capitalized pursuant to GAAP. (2) The Utility recorded these amounts to a regulatory account since they are probable of recovery from, or refund to, customers in future rates.
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (Loss)	The changes, net of income tax, in PG&E Corporation’s accumulated other comprehensive income (loss) consisted of the following: Pension Other Total (in millions, net of income tax) Three Months Ended June 30, 2020 Beginning balance $ (22) $ 17 $ (5) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1 and $1, respectively) (1) 3 2 Amortization of net actuarial loss (net of taxes of $1 and $1, respectively) — (4) (4) Regulatory account transfer (net of taxes of $0 and $0, respectively) 1 1 2 Net current period other comprehensive gain (loss) — — — Ending balance $ (22) $ 17 $ (5) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.) Pension Benefits Other Total (in millions, net of income tax) Three Months Ended June 30, 2019 Beginning balance $ (21) $ 17 $ (4) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1 and $1, respectively) (1) 2 1 Amortization of net actuarial loss (net of taxes of $0, and $1, respectively) — — — Regulatory account transfer (net of taxes of $1 and $0, respectively) 1 (2) (1) Net current period other comprehensive gain (loss) — — — Ending balance $ (21) $ 17 $ (4) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.) Pension Benefits Other Benefits Total (in millions, net of income tax) Six Months Ended June 30, 2020 Beginning balance $ (22) $ 17 $ (5) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1 and $2, respectively) (2) 5 3 Amortization of net actuarial loss (net of taxes of $1 and $3, respectively) 1 (7) (6) Regulatory account transfer (net of taxes of $0 and $1, respectively) 1 2 3 Net current period other comprehensive gain (loss) — — — Ending balance $ (22) $ 17 $ (5) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.) Pension Benefits Other Benefits Total (in millions, net of income tax) Six Months Ended June 30, 2019 Beginning balance $ (21) $ 17 $ (4) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1 and $2, respectively) (2) 5 3 Amortization of net actuarial loss (net of taxes of $0 and $1, respectively) 1 (1) — Regulatory account transfer (net of taxes of $1 and $1, respectively) 1 (4) (3) Net current period other comprehensive gain (loss) — — — Ending balance $ (21) $ 17 $ (4) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.)
Summary of Revenues Disaggregated by Type of Customer	The following table presents the Utility’s revenues disaggregated by type of customer: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2020 2019 2020 2019 Electric Revenue from contracts with customers Residential $ 987 $ 994 $ 2,230 $ 2,282 Commercial 1,075 1,135 2,082 2,088 Industrial 342 326 682 619 Agricultural 368 261 491 347 Public street and highway lighting 17 16 34 33 Other (1) 269 — 203 (309) Total revenue from contracts with customers - electric 3,058 2,732 5,722 5,060 Regulatory balancing accounts (2) 377 214 753 678 Total electric operating revenue $ 3,435 $ 2,946 $ 6,475 $ 5,738 Natural gas Revenue from contracts with customers Residential $ 426 $ 343 $ 1,492 $ 1,515 Commercial 110 129 344 369 Transportation service only 296 304 643 686 Other (1) (159) (129) (180) (205) Total revenue from contracts with customers - gas 673 647 2,299 2,365 Regulatory balancing accounts (2) 425 350 65 (149) Total natural gas operating revenue 1,098 997 2,364 2,216 Total operating revenues $ 4,533 $ 3,943 $ 8,839 $ 7,954 (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.

REGULATORY ASSETS, LIABILITIE_2

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Tables)	6 Months Ended
	Jun. 30, 2020
Regulated Operations [Abstract]
Long-Term Regulatory Assets	Long-term regulatory assets are comprised of the following: Balance at (in millions) June 30, 2020 December 31, 2019 Pension benefits (1) $ 1,757 $ 1,823 Environmental compliance costs 1,082 1,062 Utility retained generation (2) 205 228 Price risk management 183 124 Unamortized loss, net of gain, on reacquired debt 56 63 Catastrophic event memorandum account (3) 646 656 Wildfire expense memorandum account (4) 423 423 Fire hazard prevention memorandum account (5) 261 259 Fire risk mitigation memorandum account (6) 98 95 Wildfire mitigation plan memorandum account (7) 993 558 Deferred income taxes (8) 583 252 Insurance premium costs (9) 481 — Other 739 523 Total long-term regulatory assets $ 7,507 $ 6,066 (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. Recovery of CEMA costs are subject to CPUC review and approval. (4) Includes incremental wildfire liability insurance premium costs the CPUC approved for tracking in June 2018 for the period July 26, 2017 through December 31, 2019. Recovery of WEMA costs are subject to CPUC review and approval. (5) Includes costs associated with the implementation of regulations and requirements adopted to protect the public from potential fire hazards associated with overhead power line facilities and nearby aerial communication facilities that have not been previously authorized in another proceeding. Recovery of FHPMA costs are subject to CPUC review and approval. (6) Includes costs associated with the 2019 Wildfire Mitigation Plan for the period January 1, 2019 through June 4, 2019. Recovery of FRMMA costs are subject to CPUC review and approval. (7) Includes costs associated with the 2019 Wildfire Mitigation Plan for the period June 5, 2019 through December 31, 2019 and the 2020 Wildfire Mitigation Plan for the period of January 1, 2020 through June 30, 2020. Recovery of WMPMA costs are 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 incremental liability insurance premium costs for the period January 1, 2020 through June 30, 2020. Approval of costs is pending final 2020 GRC decision.
Long-Term Regulatory Liabilities	Long-term regulatory liabilities are comprised of the following: Balance at (in millions) June 30, 2020 December 31, 2019 Cost of removal obligations (1) $ 6,747 $ 6,456 Recoveries in excess of AROs (2) 290 393 Public purpose programs (3) 917 817 Employee benefit plans (4) 770 750 Other 917 854 Total long-term regulatory liabilities $ 9,641 $ 9,270 (1) Represents the cumulative differences between the recorded costs to remove assets and amounts collected in rates for expected costs to remove assets. (2) Represents the cumulative differences between ARO expenses and amounts collected in rates. Decommissioning costs related to the Utility’s nuclear facilities are recovered through rates and are placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on these nuclear decommissioning trust investments. (See Note 9 below.) (3) Represents amounts received from customers designated for public purpose program costs expected to be incurred beyond the next 12 months, primarily related to energy efficiency programs.
Regulatory Balancing Accounts Receivable	Current regulatory balancing accounts receivable and payable are comprised of the following: Receivable Balance at (in millions) June 30, 2020 December 31, 2019 Electric distribution $ 255 $ — Electric transmission — 9 Gas distribution and transmission 119 363 Energy procurement 1,300 901 Public purpose programs 216 209 Other 748 632 Total regulatory balancing accounts receivable $ 2,638 $ 2,114
Regulatory Balancing Accounts Payable	Payable Balance at (in millions) June 30, 2020 December 31, 2019 Electric distribution $ — $ 31 Electric transmission 197 119 Gas distribution and transmission 33 45 Energy procurement 731 649 Public purpose programs 547 559 Other 407 394 Total regulatory balancing accounts payable $ 1,915 $ 1,797

DEBT (Tables)

DEBT (Tables)	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Schedule of Debtor-in-Possession Financing	The following table summarizes the Utility’s outstanding borrowings and availability under the DIP Facilities at June 30, 2020: (in millions) Termination Aggregate Limit Term Loan Borrowings Revolver Letters of Credit Outstanding Aggregate DIP Facilities December 2020 $ 5,500 $ 2,000 $ — $ 904 $ 2,596
Schedule of Debt	The following table summarizes PG&E Corporation’s and the Utility’s debt: Balance at (in millions) Contractual Interest Rates June 30, 2020 December 31, 2019 Treatment under Plan on the Effective Date (1) Pre-Petition Debt (2) PG&E Corporation Borrowings under Pre-Petition Credit Facility PG&E Corporation Revolving Credit Facilities - Stated Maturity: 2022 variable rate (3) $ 300 $ 300 Repaid in cash (12) Other borrowings Term Loan - Stated Maturity: 2020 variable rate (4) 350 350 Repaid in cash (12) Less: current portion (5) (650) — Total PG&E Corporation Pre-Petition Long-Term Debt, net of current portion — 650 Utility Senior Notes - Stated Maturity: 2020 through 2022 2.45% to 4.25% 1,750 1,750 Exchanged (13) 2023 through 2028 2.95% to 4.65% 5,025 5,025 Reinstated (14) 2034 through 2040 5.40% to 6.35% 5,700 5,700 Exchanged (15) 2041 through 2042 3.75% to 4.50% 1,000 1,000 Reinstated (14) 2043 5.13% 500 500 Exchanged (15) 2043 through 2047 3.95% to 4.75% 3,550 3,550 Reinstated (14) Total Pre-Petition Senior Notes 17,525 17,525 Pollution Control Bonds - Stated Maturity: Series 2008 F and 2010 E, due 2026 1.75% 100 100 Repaid in cash (12) Series 2009 A-B, due 2026 variable rate (6) 149 149 Exchanged (16) Series 1996 C, E, F, 1997 B due 2026 variable rate (7) 614 614 Exchanged (16) Less: current portion (5) (100) — Total Pre-Petition Pollution Control Bonds, net of current portion 763 863 Borrowings under Pre-Petition Credit Facilities Utility Revolving Credit Facilities - Stated Maturity: 2022 variable rate (8) 2,888 2,888 Exchanged (16) Other borrowings: Term Loan - Stated Maturity: 2019 variable rate (9) 250 250 Exchanged (16) Total Borrowings under Pre-Petition Credit Facility 3,138 3,138 Total Utility Pre-Petition Debt, net of current portion 21,426 21,526 Total PG&E Corporation Consolidated Pre-Petition Debt, net of current portion $ 21,426 $ 22,176 New Debt PG&E Corporation Term Loan - Stated Maturity: 2025 variable rate (10) $ 2,750 $ — Senior Secured Notes due 2028 5.00% 1,000 — Senior Secured Notes due 2030 5.25% 1,000 — Unamortized discount, net of premium and debt issuance costs (93) — Total PG&E Corporation New Debt 4,657 — Utility First Mortgage Bonds - Stated Maturity: 2022 variable rate (11) 500 — 2022 1.75% 2,500 — 2027 2.10% 1,000 — 2031 2.50% 2,000 — 2040 3.30% 1,000 — 2050 3.50% 1,925 — Unamortized discount, net of premium and debt issuance costs (88) — Total Utility New Debt 8,837 — Total PG&E Corporation Consolidated New Debt $ 13,494 $ — Total Utility Long-Term Debt $ 30,263 Total PG&E Corporation Consolidated Long-Term Debt $ 34,920 (1) The treatments of pre-petition debt under the Plan, described in this column relate only to the treatment of principal amounts and not pre-petition or post-petition interest. See “Restructuring Support Agreement with the Ad Hoc Noteholder Committee” in Note 2. (2) As of December 31, 2019, debt subject to compromise was reported at the amounts expected to be allowed by the Bankruptcy Court. As of June 30, 2020, this debt is no longer subject to compromise. Total Pre-Petition Debt does not include accrued contractual interest of $280 million for the Utility to the Petition Date. Total Pre-Petition Debt also does not include post-petition interest of $25 million and $986 million for PG&E Corporation and the Utility, respectively, in accordance with the terms of the Noteholder RSA. See Note 2 for further details. (3) At June 30, 2020, the contractual LIBOR-based interest rate on loans was 1.64%. (4) At June 30, 2020, the contractual LIBOR-based interest rate on the term loan was 1.37%. (5) At June 30, 2020, the amount outstanding under PG&E Corporation’s Revolving Credit Facilities were reclassified to “Short-term borrowings” on the Condensed Consolidated Balance Sheet. At June 30, 2020, the amounts outstanding under PG&E Corporation’s Term Loan and the Utility’s Series 2008 F and 2010 E Pollution Control Bonds were reclassified to “Long-term debt, classified as current” on the Condensed Consolidated Balance Sheets. (6) At June 30, 2020, the contractual interest rate on the letter of credit facilities supporting these bonds was 6.45%. (7) At June 30, 2020, the contractual interest rate on the letter of credit facilities supporting these bonds ranged from 6.45% to 6.58%. (8) At June 30, 2020, the contractual LIBOR-based interest rate on the loans was 1.44%. (9) At June 30, 2020, the contractual LIBOR-based interest rate on the term loan was 0.77%. (10) At June 30, 2020, the contractual LIBOR-based interest rate on the loans was 5.50% (11) At June 30, 2020, the contractual LIBOR-based interest rate on the first mortgage bonds was 1.80% (12) In accordance with the Plan, these borrowings were repaid in cash on July 1, 2020. (13) In accordance with the Plan, on July 1, 2020, the Utility issued $875 million aggregate principal amount of 3.45% first mortgage bonds due 2025 and $875 million aggregate principal amount of 3.75% first mortgage bonds due 2028, in satisfaction of these Senior Notes. (14) In accordance with the Plan, these Senior Notes were reinstated on July 1, 2020. (15) In accordance with the Plan, on July 1, 2020, the Utility issued $3.1 billion aggregate principal amount of 4.55% first mortgage bonds due 2030 and $3.1 billion aggregate principal amount of 4.95% first mortgage bonds due 2050, in satisfaction of these Senior Notes. (16) In accordance with the Plan, on July 1, 2020, the Utility issued $1.95 billion aggregate principal amount of 3.15% first mortgage bonds due 2026 and $1.95 billion aggregate principal amount of 4.50% first mortgage bonds due 2040, in satisfaction of these pre-petition liabilities.

EARNINGS PER SHARE (Tables)

EARNINGS PER SHARE (Tables)	6 Months Ended
	Jun. 30, 2020
Earnings Per Share [Abstract]
Reconciliation of PG&E Corporation's Income Available for Common Shareholders and Weighted Average Common Shares Outstanding for Calculating Diluted EPS	The following is a reconciliation of PG&E Corporation’s income available for common shareholders and weighted average common shares outstanding for calculating diluted EPS: Three Months Ended June 30, Six Months Ended June 30, (in millions, except per share amounts) 2020 2019 2020 2019 Loss attributable to common shareholders $ (1,972) $ (2,553) $ (1,601) $ (2,420) Weighted average common shares outstanding, basic 529 529 529 528 Add incremental shares from assumed conversions: Employee share-based compensation — — — — Weighted average common shares outstanding, diluted 529 529 529 528 Total loss per common share, diluted $ (3.73) $ (4.83) $ (3.03) $ (4.58)

DERIVATIVES (Tables)

DERIVATIVES (Tables)	6 Months Ended
	Jun. 30, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Volumes Of Outstanding Derivative Contracts	The volumes of the Utility’s outstanding derivatives were as follows: Contract Volume at Underlying Product Instruments June 30, 2020 December 31, 2019 Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 199,547,057 131,896,159 Options 33,810,000 14,720,000 Electricity (Megawatt-hours) Forwards, Futures and Swaps 9,754,771 18,675,852 Options 1,620,000 — Congestion Revenue Rights (3) 287,183,280 308,467,999 (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.
Schedule of Offsetting Assets	At June 30, 2020, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Balance Current assets – other $ 46 $ (7) $ 29 $ 68 Other noncurrent assets – other 121 — — 121 Current liabilities – other (44) 7 — (37) Noncurrent liabilities – other (183) — — (183) Total commodity risk $ (60) $ — $ 29 $ (31) At December 31, 2019, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 36 $ (6) $ 4 $ 34 Other noncurrent assets – other 130 (6) — 124 Current liabilities – other (31) 6 2 (23) Noncurrent liabilities – other (130) 6 — (124) Total commodity risk $ 5 $ — $ 6 $ 11
Schedule of Offsetting Liabilities	At June 30, 2020, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Balance Current assets – other $ 46 $ (7) $ 29 $ 68 Other noncurrent assets – other 121 — — 121 Current liabilities – other (44) 7 — (37) Noncurrent liabilities – other (183) — — (183) Total commodity risk $ (60) $ — $ 29 $ (31) At December 31, 2019, the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Netting Cash Collateral Total Derivative Current assets – other $ 36 $ (6) $ 4 $ 34 Other noncurrent assets – other 130 (6) — 124 Current liabilities – other (31) 6 2 (23) Noncurrent liabilities – other (130) 6 — (124) Total commodity risk $ 5 $ — $ 6 $ 11

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	6 Months Ended
	Jun. 30, 2020
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 June 30, 2020 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 718 $ — $ — $ — $ 718 Nuclear decommissioning trusts Short-term investments 34 — — — 34 Global equity securities 2,135 — — — 2,135 Fixed-income securities 794 753 — — 1,547 Assets measured at NAV — — — — 20 Total nuclear decommissioning trusts (2) 2,963 753 — — 3,736 Price risk management instruments (Note 8) Electricity — 14 148 21 183 Gas — 5 — 1 6 Total price risk management instruments — 19 148 22 189 Rabbi trusts Fixed-income securities — 105 — — 105 Life insurance contracts — 77 — — 77 Total rabbi trusts — 182 — — 182 Long-term disability trust Short-term investments 6 — — — 6 Assets measured at NAV — — — — 150 Total long-term disability trust 6 — — — 156 TOTAL ASSETS $ 3,687 $ 954 $ 148 $ 22 $ 4,981 Liabilities: Equity Backstop Commitments and Forward Stock Purchase Agreements $ — $ 1,500 $ — $ — $ 1,500 Price risk management instruments (Note 8) Electricity — 9 214 (6) 217 Gas — 4 — (1) 3 TOTAL LIABILITIES $ — $ 1,513 $ 214 $ (7) $ 1,720 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $540 million, primarily related to deferred taxes on appreciation of investment value. Fair Value Measurements December 31, 2019 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 1,323 $ — $ — $ — $ 1,323 Nuclear decommissioning trusts Short-term investments 6 — — — 6 Global equity securities 2,086 — — — 2,086 Fixed-income securities 862 728 — — 1,590 Assets measured at NAV — — — — 21 Total nuclear decommissioning trusts (2) 2,954 728 — — 3,703 Price risk management instruments (Note 8) Electricity — 2 161 (11) 152 Gas — 3 — 3 6 Total price risk management instruments — 5 161 (8) 158 Rabbi trusts Fixed-income securities — 100 — — 100 Life insurance contracts — 73 — — 73 Total rabbi trusts — 173 — — 173 Long-term disability trust Short-term investments 10 — — — 10 Assets measured at NAV — — — — 156 Total long-term disability trust 10 — — — 166 TOTAL ASSETS $ 4,287 $ 906 $ 161 $ (8) $ 5,523 Liabilities: Price risk management instruments (Note 8) Electricity $ 1 $ 2 $ 156 $ (13) $ 146 Gas — 2 — (1) 1 TOTAL LIABILITIES $ 1 $ 4 $ 156 $ (14) $ 147 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $530 million, primarily related to deferred taxes on appreciation of investment value.
Level 3 Measurements and Sensitivity Analysis	Fair Value at (in millions) June 30, 2020 Fair Value Measurement Assets Liabilities Valuation Unobservable Range (1) / Weighted-Average Price (2) Congestion revenue rights $ 135 $ 59 Market approach CRR auction prices $(23.93) - $25.51 / 0.27 Power purchase agreements $ 13 $ 155 Discounted cash flow Forward prices $11.83 - $64.30 / 31.81 (1) Represents price per megawatt-hour. (2) Unobservable inputs were weighted by the relative fair value of the instruments. Fair Value at (in millions) December 31, 2019 Fair Value Measurement Assets Liabilities Valuation Technique Unobservable Input Range (1) /Weighted-Average Price (2) Congestion revenue rights $ 140 $ 44 Market approach CRR auction prices $(20.20) - $20.20 / 0.28 Power purchase agreements $ 21 $ 112 Discounted cash flow Forward prices $11.77 - $59.38 / 33.62 (1) Represents price per megawatt-hour. (2) Unobservable inputs were weighted by the relative fair value of the instruments.
Level 3 Reconciliation	The following table presents the reconciliation for Level 3 instruments for the three and six months ended June 30, 2020 and 2019: Price Risk Management Instruments (in millions) 2020 2019 Asset (liability) balance as of April 1 $ (5) $ 129 Net realized and unrealized losses: Included in regulatory assets and liabilities or balancing accounts (1) (61) (20) Asset (liability) balance as of June 30 $ (66) $ 109 (1) The costs related to price risk management activities are fully passed through to customers in rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted. Price Risk Management Instruments (in millions) 2020 2019 Asset balance as of January 1 $ 5 $ 95 Net realized and unrealized gains (losses): Included in regulatory assets and liabilities or balancing accounts (1) (71) 14 Asset (liability) balance as of June 30 $ (66) $ 109 (1) The costs related to price risk management activities are fully passed through to customers in rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted.
Carrying Amount and Fair Value of Financial Instruments	The carrying amount and fair value of PG&E Corporation’s and the Utility’s long-term debt instruments were as follows (the table below excludes financial instruments with carrying values that approximate their fair values): At June 30, 2020 At December 31, 2019 (in millions) Carrying Amount Level 2 Fair Value Carrying Amount (1) Level 2 Fair Value (1)(2) Debt (Note 5) PG&E Corporation $ 2,257 $ 2,005 $ — $ — Utility 25,962 28,853 1,500 1,500 (1) On January 29, 2019 PG&E Corporation and the Utility filed for Chapter 11 protection. Debt held by PG&E Corporation and the Utility became debt subject to compromise and is valued at the allowed claim amount. For more information, see Note 2 and Note 5. (2) The fair value of the Utility pre-petition debt was $17.9 billion at December 31, 2019. For more information, see Note 2 and Note 5.
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) As of June 30, 2020 Amortized Total Unrealized Gains Total Unrealized Losses Total Fair Nuclear decommissioning trusts Short-term investments $ 34 $ — $ — $ 34 Global equity securities 646 1,524 (15) 2,155 Fixed-income securities 1,386 165 (4) 1,547 Total (1) $ 2,066 $ 1,689 $ (19) $ 3,736 As of December 31, 2019 Nuclear decommissioning trusts Short-term investments $ 6 $ — $ — $ 6 Global equity securities 500 1,609 (2) 2,107 Fixed-income securities 1,505 89 (4) 1,590 Total (1) $ 2,011 $ 1,698 $ (6) $ 3,703 (1) Represents amounts before deducting $540 million and $530 million for the periods ended June 30, 2020 and December 31, 2019, respectively, primarily related to deferred taxes on appreciation of investment value.
Schedule of Maturities on Debt Instruments	The fair value of fixed-income securities by contractual maturity is as follows: As of (in millions) June 30, 2020 Less than 1 year $ 28 1–5 years 416 5–10 years 404 More than 10 years 699 Total maturities of fixed-income securities $ 1,547
Schedule of Activity for Debt and Equity Securities	The following table provides a summary of activity for fixed income and equity securities: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2020 2019 2020 2019 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 254 $ 171 $ 787 $ 517 Gross realized gains on securities 8 56 26 22 Gross realized losses on securities (12) (26) (21) (7)

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES (Tables)	6 Months Ended
	Jun. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Schedule of Insurance Receivable	The balances for insurance receivables with respect to wildfires are included in Other accounts receivable in PG&E Corporation’s and the Utility’s Condensed Consolidated Balance Sheets: Insurance Receivable (in millions) 2019 Kincade fire 2018 Camp fire 2017 Northern California wildfires 2015 Butte fire Total Balance at December 31, 2019 $ — $ 1,380 $ 807 $ 50 $ 2,237 Accrued insurance recoveries 430 — — — 430 Reimbursements — (408) (121) — (529) Balance at June 30, 2020 $ 430 $ 972 $ 686 $ 50 $ 2,138

OTHER CONTINGENCIES AND COMMI_2

OTHER CONTINGENCIES AND COMMITMENTS (Tables)	6 Months Ended
	Jun. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Schedule of Expense and Capital Expenditures	The amounts set forth in the table below include actual recorded costs and forecasted cost estimates for expenses and capital expenditures which the Utility has incurred or will incur to comply with its legal obligations to provide safe and reliable service. (in millions) Description (1) Expense Capital Total Distribution Safety Inspections and Repairs Expense (FRMMA/WMPMA) (2) $ 236 $ — $ 236 Transmission Safety Inspections and Repairs Expense (TO) (3) 433 — 433 Vegetation Management Support Costs (FHPMA) 36 — 36 2017 Northern California Wildfires CEMA Expense and Capital (CEMA) 82 66 148 2018 Camp Fire CEMA Expense (CEMA) 435 — 435 2018 Camp Fire CEMA Capital for Restoration (CEMA) — 253 253 2018 Camp Fire CEMA Capital for Temporary Facilities (CEMA) (4) — 84 84 Total $ 1,222 $ 403 $ 1,625 (1) Unless indicated otherwise, all amounts included in the table reflect actual recorded costs for 2019. (2) Includes $29 million forecasted for 2020. (3) Transmission amounts are under the FERC’s regulatory authority.
Schedule of Environmental Remediation Liability	The Utility’s environmental remediation liability is primarily included in non-current liabilities on the Condensed Consolidated Balance Sheets and is comprised of the following: Balance at (in millions) June 30, 2020 December 31, 2019 Topock natural gas compressor station $ 339 $ 362 Hinkley natural gas compressor station 135 138 Former manufactured gas plant sites owned by the Utility or third parties (1) 680 568 Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites (2) 102 101 Fossil fuel-fired generation facilities and sites (3) 103 106 Total environmental remediation liability $ 1,359 $ 1,275 (1) Primarily driven by the following sites: San Francisco Beach Street, Vallejo, and San Francisco East Harbor. (2) Primarily driven by Geothermal landfill and Shell Pond site.

ORGANIZATION AND BASIS OF PRE_2

ORGANIZATION AND BASIS OF PRESENTATION (Details)	6 Months Ended
	Jun. 30, 2020numberOfSegment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of operating segments (segment)	1

BANKRUPTCY FILING (Plan of Reor

BANKRUPTCY FILING (Plan of Reorganization and Restructuring Support Agreements) (Details) - USD ($)	Jul. 01, 2020	Jun. 25, 2020	Jul. 31, 2020	Jun. 30, 2020	Jun. 30, 2020	Jul. 27, 2020	Jan. 22, 2020	Dec. 31, 2019	Oct. 11, 2019	Sep. 22, 2019
Debt Instrument [Line Items]
Subrogation claims, professional fees										$ 55,000,000
Proceeds through the issuance of common stock and other equity-linked instruments		$ 3,970,000,000
Professional fees							$ 106,000,000
Subsequent event
Debt Instrument [Line Items]
Proceeds through the issuance of common stock and other equity-linked instruments	$ 9,000,000,000		$ 9,000,000,000
Subsequent event | Settling Public Entities
Debt Instrument [Line Items]
Litigation payment	1,000,000,000
Litigation, segregated reimbursement fund	10,000,000
Fire Victim Trust | Subsequent event
Debt Instrument [Line Items]
Cash contribution by company	5,400,000,000
Deferred cash	$ 1,350,000,000
Percentage of common stock owned, Fire Victim Trust if common issues additional shares	22.19%
Litigation payment, fund, cash	$ 5,400,000,000
Subrogation Wildfire Trust | Subsequent event
Debt Instrument [Line Items]
Subrogation claims, professional fees	52,000,000
Litigation payment, fund, cash	11,000,000,000
Noteholder RSA Breach Claim | Subsequent event
Debt Instrument [Line Items]
Administrative claims						$ 250,000,000
Transfer of backstop commitments						$ 2,000,000,000
Bridge Loan
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity									$ 10,825,000,000
Bridge Loan | Secured debt
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity									5,825,000,000
Bridge Loan | Unsecured debt
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity									$ 5,000,000,000
New PG&E Corporation Debt | Subsequent event
Debt Instrument [Line Items]
Issuance	4,750,000,000
PG&E Corporation
Debt Instrument [Line Items]
Legal fees							6,000,000
Facility fees				$ 4,000,000	$ 40,000,000
PG&E Corporation | Subsequent event
Debt Instrument [Line Items]
Debt discount	102,000,000
PG&E Corporation | New Utility Debt | Subsequent event
Debt Instrument [Line Items]
Issuance	23,775,000,000
PG&E Corporation | New Utility Short-Term Bonds
Debt Instrument [Line Items]
Debt instrument, face amount							$ 875,000,000
Stated interest rate							3.75%
PG&E Corporation | New Utility Short-Term Bonds | Subsequent event
Debt Instrument [Line Items]
Issuance	1,750,000,000
PG&E Corporation | New Debt Securities or Bank Debt | Subsequent event
Debt Instrument [Line Items]
Issuance	11,925,000,000
Expected repayment	6,000,000,000
PG&E Corporation | Utility Short-Term Senior Notes
Debt Instrument [Line Items]
Debt instrument, face amount							$ 1,750,000,000
PG&E Corporation | Utility Short-Term Secured Notes, First Mortgage Bond Due 2025
Debt Instrument [Line Items]
Debt instrument, face amount							$ 875,000,000
Stated interest rate							3.45%
PG&E Corporation | Senior Note Due March 1, 2034
Debt Instrument [Line Items]
Stated interest rate							6.05%
PG&E Corporation | Utility Long-Term Senior Notes
Debt Instrument [Line Items]
Debt instrument, face amount							$ 6,200,000,000
Stated interest rate							5.00%
PG&E Corporation | Utility Long-Term Secured Notes, First Mortgage Bond Due 2030
Debt Instrument [Line Items]
Debt instrument, face amount							$ 3,100,000,000
Stated interest rate							4.55%
PG&E Corporation | New Utility Long-Term Bonds
Debt Instrument [Line Items]
Debt instrument, face amount							$ 3,100,000,000
Stated interest rate							4.95%
PG&E Corporation | New Utility Long-Term Bonds | Subsequent event
Debt Instrument [Line Items]
Issuance	6,200,000,000
PG&E Corporation | Senior Note Due December 1, 2047
Debt Instrument [Line Items]
Stated interest rate							3.95%
PG&E Corporation | Utility Reinstated Senior Notes
Debt Instrument [Line Items]
Debt, outstanding							$ 9,575,000,000
PG&E Corporation | Utility Funded Debt
Debt Instrument [Line Items]
Debt instrument, face amount							$ 1,950,000,000
Stated interest rate							3.15%
PG&E Corporation | New Utility Funded Debt Exchange Bond
Debt Instrument [Line Items]
Stated interest rate							4.50%
PG&E Corporation | New Utility Funded Debt Exchange Bond | Subsequent event
Debt Instrument [Line Items]
Issuance	3,900,000,000
PG&E Corporation | Pre-Petition Debt | Subsequent event
Debt Instrument [Line Items]
Issuance	9,575,000,000
Pacific Gas & Electric Co
Debt Instrument [Line Items]
Subrogation claims, professional fees				52,000,000	52,000,000
Facility fees				2,000,000	33,000,000
Probable of recovery					18,000,000
Pacific Gas & Electric Co | Utility Reinstated Senior Notes | Subsequent event
Debt Instrument [Line Items]
Debt instrument, face amount	9,600,000,000
Pacific Gas & Electric Co | Pollution Control Bonds - Series 2008 F and 2010 E, due 2026
Debt Instrument [Line Items]
Pollution control bonds				$ 100,000,000	$ 100,000,000			$ 100,000,000
Stated interest rate				1.75%	1.75%
Pacific Gas & Electric Co | Pollution Control Bonds - Series 2008 F and 2010 E, due 2026 | Subsequent event
Debt Instrument [Line Items]
Pollution control bonds	$ 100,000,000

BANKRUPTCY FILING (Equity Finan

BANKRUPTCY FILING (Equity Financing) (Details) - USD ($) $ / shares in Units, shares in Thousands	Jul. 01, 2020	Jun. 25, 2020	Jul. 31, 2020	Jun. 30, 2020	Sep. 30, 2020	Aug. 03, 2020	Jun. 19, 2020	Mar. 06, 2020
Debt Instrument [Line Items]
Proceeds through the issuance of common stock and other equity-linked instruments		$ 3,970,000,000
Backstop commitment premium, expense				$ 1,100,000,000
Share price (in dollar per share)				$ 8.87
Additional backstop commitment premium, expense				$ 444,000,000
Professional legal fees				34,000,000
Professional non-legal fees				19,000,000
Professional fees				49,000,000
Purchase price							$ 523,000,000
Settlement price (in dollars per share)							$ 9.50
Expiration period		30 days
Backstop Parties
Debt Instrument [Line Items]
Debt commitment letters, required equity funding		$ 523,000,000						$ 12,000,000,000
Forward stock purchase agreement, common stock issues, pro rata (in shares)		50,000
Offerings
Debt Instrument [Line Items]
Proceeds through the issuance of common stock and other equity-linked instruments				5,750,000,000
Option Amount
Debt Instrument [Line Items]
Proceeds through the issuance of common stock and other equity-linked instruments				$ 523,000,000
Forecast
Debt Instrument [Line Items]
Additional backstop commitment premium, expense					$ 27,000,000
Additional forward stock purchase agreement, expense					$ 8,000,000
Subsequent event
Debt Instrument [Line Items]
Proceeds through the issuance of common stock and other equity-linked instruments	$ 9,000,000,000		$ 9,000,000,000
Equity backstop commitments, shares (in shares)	119,000
Equity backstop commitments, value	$ 12,000,000,000
Share price (in dollar per share)	$ 9.03
PG&E Corporation | Subsequent event
Debt Instrument [Line Items]
Forward stock purchase, redemption amount						$ 120,500,000
PG&E Corporation | Subsequent event | Backstop Parties
Debt Instrument [Line Items]
Transfer of common stock to counterparty (in shares)						42,300

BANKRUPTCY FILING (Schedule of

BANKRUPTCY FILING (Schedule of Liabilities Subject to Compromise) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jul. 24, 2020	Dec. 31, 2019
Liabilities Subject to Compromise, Period Increase (Decrease) [Roll Forward]
Financing debt, beginning balance	$ 23,116
Wildfire-related claims, beginning balance	25,548
Trade creditors, beginning balance	1,188
Non-qualified benefit plan, beginning balance	157
2001 bankruptcy disputed claims, beginning balance	234
Customer deposits & advances, beginning balance	71
Other, beginning balance	232
Liabilities Subject to Compromise, beginning balance	50,546
Liabilities Subject to Compromise, ending balance	0
Financing debt, ending balance	0
Wildfire-related claims, ending balance	0
Trade creditors, ending balance	0
Non-qualified benefit plan, ending balance	0
2001 bankruptcy disputed claims, ending balance	0
Customer deposits & advances, ending balance	0
Other, ending balance	0
Accounts payable - other	631		$ 566
Disputed claims and customer refunds	238		0
Interest payable	1,363		4
Debt financial instrument	34,920
Short-term borrowings	300		0
Long-term debt, classified as current	450		0
Other current liabilities	3,605		1,254
Other non-current liabilities	4,423		2,573
Pension and other post-retirement benefits	1,941		1,884
Accounts payable - trade creditors	3,399		1,954
Wildfire-related Claims	26,143		0
Change in Estimated Allowed Claim
Liabilities Subject to Compromise, Period Increase (Decrease) [Roll Forward]
Financing debt, change	351
Wildfire-related claims, change	18
Trade creditors, change	6
Non-qualified benefit plan, change	0
2011 bankruptcy disputed claims, change	4
Customer deposits & advances, change	12
Other, change	59
Liabilities Subject to Compromise, change	450
Cash Payment
Liabilities Subject to Compromise, Period Increase (Decrease) [Roll Forward]
Financing debt, change	0
Wildfire-related claims, change	(23)
Trade creditors, change	(14)
Non-qualified benefit plan, change	0
2011 bankruptcy disputed claims, change	0
Customer deposits & advances, change	0
Other, change	0
Liabilities Subject to Compromise, change	(37)
Reclassified
Liabilities Subject to Compromise, Period Increase (Decrease) [Roll Forward]
Financing debt, change	(23,467)
Wildfire-related claims, change	(25,543)
Trade creditors, change	(1,180)
Non-qualified benefit plan, change	(157)
2011 bankruptcy disputed claims, change	(238)
Customer deposits & advances, change	(83)
Other, change	(291)
Liabilities Subject to Compromise, change	(50,959)
Accounts payable - other	8.6
Disputed claims and customer refunds	237.6
Interest payable	1,347.4
Debt financial instrument	21,425.7
Short-term borrowings	300
Long-term debt, classified as current	450
Other current liabilities	301
Other non-current liabilities	97.9
Pension and other post-retirement benefits	121.3
Accounts payable - trade creditors	1,126.9
Wildfire-related Claims	25,542.7
Pacific Gas & Electric Co
Liabilities Subject to Compromise, Period Increase (Decrease) [Roll Forward]
Financing debt, beginning balance	22,450
Wildfire-related claims, beginning balance	25,548
Trade creditors, beginning balance	1,183
Non-qualified benefit plan, beginning balance	20
2001 bankruptcy disputed claims, beginning balance	234
Customer deposits & advances, beginning balance	71
Other, beginning balance	230
Liabilities Subject to Compromise, beginning balance	49,736
Liabilities Subject to Compromise, ending balance	0
Financing debt, ending balance	0
Wildfire-related claims, ending balance	0
Trade creditors, ending balance	0
Non-qualified benefit plan, ending balance	0
2001 bankruptcy disputed claims, ending balance	0
Customer deposits & advances, ending balance	0
Other, ending balance	0
Accounts payable - other	717		675
Disputed claims and customer refunds	238		0
Interest payable	1,331		4
Debt financial instrument	30,263
Long-term debt, classified as current	100		0
Other current liabilities	1,579		1,263
Other non-current liabilities	4,455		2,626
Pension and other post-retirement benefits	1,836		1,884
Accounts payable - trade creditors	3,382		1,949
Wildfire-related Claims	26,143		$ 0
Pacific Gas & Electric Co | Subsequent event
Liabilities Subject to Compromise, Period Increase (Decrease) [Roll Forward]
Accounts payable, trade		$ 290
PG&E Corporation
Liabilities Subject to Compromise, Period Increase (Decrease) [Roll Forward]
Financing debt, beginning balance	666
Wildfire-related claims, beginning balance	0
Trade creditors, beginning balance	5
Non-qualified benefit plan, beginning balance	137
2001 bankruptcy disputed claims, beginning balance	0
Customer deposits & advances, beginning balance	0
Other, beginning balance	2
Liabilities Subject to Compromise, beginning balance	810
Liabilities Subject to Compromise, ending balance	0
Financing debt, ending balance	0
Wildfire-related claims, ending balance	0
Trade creditors, ending balance	0
Non-qualified benefit plan, ending balance	0
2001 bankruptcy disputed claims, ending balance	0
Customer deposits & advances, ending balance	0
Other, ending balance	$ 0
PG&E Corporation | Subsequent event
Liabilities Subject to Compromise, Period Increase (Decrease) [Roll Forward]
Accounts payable, trade		$ 0.4

BANKRUPTCY FILING (Chapter 11 C

BANKRUPTCY FILING (Chapter 11 Claims Process) (Details) equityUnit in Thousands, $ in Millions	Jul. 01, 2020USD ($)shares	Aug. 03, 2020equityUnitshares	Jun. 30, 2020proofOfClaim	Dec. 31, 2019USD ($)	Jun. 30, 2018lawsuit
Debt Instrument [Line Items]
Proofs of claims | proofOfClaim			100,000
Insurance from wildfire events				$ 2,500
Satisfaction of HoldCo Rescission or Damage Claims and Subordinated Debt
Debt Instrument [Line Items]
Number of lawsuits filed against company (lawsuit, complaint) | lawsuit					3
Subsequent event
Debt Instrument [Line Items]
Plan of reorganization, future tax benefits payment agreement	$ 1,350
Plan of reorganization, tax benefits payment agreement	$ 1,350
Transfer of shares to Fire Victim Trust (in shares) | shares	477,000,000
Option to purchase additional contracts (in equity units) | equityUnit		1,450
Transfer of shares to Fire Victim Trust, additional (in shares) | shares		748,415
Subsequent event | Minimum
Debt Instrument [Line Items]
Plan of reorganization, tax benefits payment agreement	$ 650
Subsequent event | Subrogation Wildfire Trust
Debt Instrument [Line Items]
Litigation payment, funded	100
Litigation payment, fund, segregated escrow	11,000
Subsequent event | Settling Public Entities
Debt Instrument [Line Items]
Litigation payment	$ 1,000

BANKRUPTCY FILING (Reorganizati

BANKRUPTCY FILING (Reorganization Items, Net) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Pacific Gas & Electric Co
Debt Instrument [Line Items]
Payments for reorganization items	$ 90	$ 13	$ 207	$ 78
Probable of recovery			18
PG&E Corporation
Debt Instrument [Line Items]
Payments for reorganization items	$ 33	$ 2	$ 90	$ 15

BANKRUPTCY FILING (Schedule o_2

BANKRUPTCY FILING (Schedule of Debtor Reorganization Items) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Reorganizations [Line Items]
Debtor-in-possession financing costs	$ 1,000,000	$ 0	$ 3,000,000	$ 114,000,000
Legal and other	1,622,000,000	76,000,000	1,802,000,000	100,000,000
Interest income	0	(21,000,000)	(7,000,000)	(32,000,000)
Trustee fees	1,000,000	1,000,000	2,000,000	1,000,000
Total reorganization items, net	1,624,000,000	56,000,000	1,800,000,000	183,000,000
PG&E Corporation
Reorganizations [Line Items]
Debtor-in-possession financing costs	0	0	0	17,000,000
Legal and other	1,513,000,000	1,000,000	1,597,000,000	2,000,000
Interest income	0	(3,000,000)	(2,000,000)	(5,000,000)
Trustee fees	0	1,000,000	1,000,000	1,000,000
Total reorganization items, net	1,513,000,000	(1,000,000)	1,596,000,000	15,000,000
Fees paid to the U.S. Trustee	475,232	416,667	724,232	416,667
Utility
Reorganizations [Line Items]
Debtor-in-possession financing costs	1,000,000	0	3,000,000	97,000,000
Legal and other	109,000,000	75,000,000	205,000,000	98,000,000
Interest income	0	(18,000,000)	(5,000,000)	(27,000,000)
Trustee fees	1,000,000	0	1,000,000	0
Total reorganization items, net	111,000,000	57,000,000	204,000,000	168,000,000
Fees paid to the U.S. Trustee	$ 561,000	$ 250,000	$ 824,930	$ 250,000

SUMMARY OF SIGNIFICANT ACCOUN_4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Components of Net Periodic Benefit Cost) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	$ 132	$ 111	$ 264	$ 222
Interest cost	179	190	357	379
Expected return on plan assets	(261)	(226)	(522)	(453)
Amortization of prior service cost	(2)	(2)	(3)	(3)
Amortization of net actuarial loss	1	0	2	1
Net periodic benefit cost	49	73	98	146
Regulatory account transfer	34	10	68	21
Total	83	83	166	167
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	16	14	31	28
Interest cost	15	19	31	38
Expected return on plan assets	(35)	(30)	(69)	(61)
Amortization of prior service cost	4	3	7	7
Amortization of net actuarial loss	(5)	(1)	(10)	(2)
Net periodic benefit cost	(5)	5	(10)	10
Regulatory account transfer	0	0	0	0
Total	$ (5)	$ 5	$ (10)	$ 10

SUMMARY OF SIGNIFICANT ACCOUN_5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Reclassifications Out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	$ 5,759	$ 13,129	$ 5,388	$ 12,903
Net current period other comprehensive gain (loss)	0	0	0	0
Ending balance	3,801	10,594	3,801	10,594
Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Net current period other comprehensive gain (loss)	0	0	0	0
Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Net current period other comprehensive gain (loss)	0	0	0	0
Accumulated Other Comprehensive Income (Loss)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(5)	(4)	(5)	(4)
Ending balance	(5)	(4)	(5)	(4)
Accumulated Other Comprehensive Income (Loss) | Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(22)	(21)	(22)	(21)
Ending balance	(22)	(21)	(22)	(21)
Accumulated Other Comprehensive Income (Loss) | Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	17	17	17	17
Ending balance	17	17	17	17
Amortization of prior service cost
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	2	1	3	3
Amortization of prior service cost | Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(1)	(1)	(2)	(2)
Amount attributable to tax	1	1	1	1
Amortization of prior service cost | Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	3	2	5	5
Amount attributable to tax	1	1	2	2
Amortization of net actuarial loss
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(4)	0	(6)	0
Amortization of net actuarial loss | Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	0	0	1	1
Amount attributable to tax	1	0	1	0
Amortization of net actuarial loss | Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(4)	0	(7)	(1)
Amount attributable to tax	1	1	3	1
Regulatory account transfer
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	2	(1)	3	(3)
Regulatory account transfer | Pension Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	1	1	1	1
Amount attributable to tax	0	1	0	1
Regulatory account transfer | Other Benefits
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	1	(2)	2	(4)
Amount attributable to tax	$ 0	$ 0	$ 1	$ 1

SUMMARY OF SIGNIFICANT ACCOUN_6

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Revenues Disaggregated by Type of Customer) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Accounting Policies [Abstract]
Period for probable revenue recovery			24 months
Pacific Gas & Electric Co
Revenue from contracts with customers
Total operating revenues	$ 4,533	$ 3,943	$ 8,839	$ 7,954
Pacific Gas & Electric Co | Electric
Revenue from contracts with customers
Total revenue from contracts with customers	3,058	2,732	5,722	5,060
Regulatory balancing accounts	377	214	753	678
Total operating revenues	3,435	2,946	6,475	5,738
Pacific Gas & Electric Co | Electric | Residential
Revenue from contracts with customers
Total revenue from contracts with customers	987	994	2,230	2,282
Pacific Gas & Electric Co | Electric | Commercial
Revenue from contracts with customers
Total revenue from contracts with customers	1,075	1,135	2,082	2,088
Pacific Gas & Electric Co | Electric | Industrial
Revenue from contracts with customers
Total revenue from contracts with customers	342	326	682	619
Pacific Gas & Electric Co | Electric | Agricultural
Revenue from contracts with customers
Total revenue from contracts with customers	368	261	491	347
Pacific Gas & Electric Co | Electric | Public street and highway lighting
Revenue from contracts with customers
Total revenue from contracts with customers	17	16	34	33
Pacific Gas & Electric Co | Electric | Other
Revenue from contracts with customers
Total revenue from contracts with customers	269	0	203	(309)
Pacific Gas & Electric Co | Natural gas
Revenue from contracts with customers
Total revenue from contracts with customers	673	647	2,299	2,365
Regulatory balancing accounts	425	350	65	(149)
Total operating revenues	1,098	997	2,364	2,216
Pacific Gas & Electric Co | Natural gas | Residential
Revenue from contracts with customers
Total revenue from contracts with customers	426	343	1,492	1,515
Pacific Gas & Electric Co | Natural gas | Commercial
Revenue from contracts with customers
Total revenue from contracts with customers	110	129	344	369
Pacific Gas & Electric Co | Natural gas | Transportation service only
Revenue from contracts with customers
Total revenue from contracts with customers	296	304	643	686
Pacific Gas & Electric Co | Natural gas | Other
Revenue from contracts with customers
Total revenue from contracts with customers	$ (159)	$ (129)	$ (180)	$ (205)

SUMMARY OF SIGNIFICANT ACCOUN_7

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Wildfire Fund) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Dec. 31, 2019
Loss Contingencies [Line Items]
Initial contribution payment	$ 4,800
Annual contribution, first payment	193
Wildfire fund liability	5,200	$ 0
Litigation contribution, net	6,500
Wildfire fund asset	6,048	$ 0
Catch up amortization expense	$ 173
Monte carlo simulation, historical data, period	12 years
Wildfire Fund asset
Loss Contingencies [Line Items]
Finite-lived intangible asset, useful life	15 years
Noncurrent liabilities – other
Loss Contingencies [Line Items]
Wildfire fund, noncurrent	$ 1,500

SUMMARY OF SIGNIFICANT ACCOUN_8

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Recently Adopted Accounting Standards) (Details) $ in Millions	Jun. 30, 2020USD ($)
Accounting Policies [Abstract]
Allowance for credit loss	$ 44

REGULATORY ASSETS, LIABILITIE_3

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Assets) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 7,507	$ 6,066
Retained generation asset costs	1,200
Pension benefits
Regulatory Assets [Line Items]
Total long-term regulatory assets	1,757	1,823
Environmental compliance costs
Regulatory Assets [Line Items]
Total long-term regulatory assets	1,082	1,062
Utility retained generation
Regulatory Assets [Line Items]
Total long-term regulatory assets	205	228
Price risk management
Regulatory Assets [Line Items]
Total long-term regulatory assets	183	124
Unamortized loss, net of gain, on reacquired debt
Regulatory Assets [Line Items]
Total long-term regulatory assets	56	63
Catastrophic event memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	646	656
Wildfire expense memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	423	423
Fire hazard prevention memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	261	259
Fire risk mitigation memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	98	95
Wild fire mitigation plan memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	993	558
Deferred income taxes
Regulatory Assets [Line Items]
Total long-term regulatory assets	583	252
Insurance premium costs
Regulatory Assets [Line Items]
Total long-term regulatory assets	481	0
Other
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 739	$ 523

REGULATORY ASSETS, LIABILITIE_4

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Liabilities) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 9,641	$ 9,270
Cost of removal obligations
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	6,747	6,456
Recoveries in excess of AROs
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	290	393
Public purpose programs
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	917	817
Employee benefit plans
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	770	750
Other
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 917	$ 854

REGULATORY ASSETS, LIABILITIE_5

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Current Regulatory Balancing Accounts, Net) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Total regulatory balancing accounts payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	$ 1,915	$ 1,797
Total regulatory balancing accounts payable | Electric distribution
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	0	31
Total regulatory balancing accounts payable | Electric transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	197	119
Total regulatory balancing accounts payable | Gas distribution and transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	33	45
Total regulatory balancing accounts payable | Energy procurement
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	731	649
Total regulatory balancing accounts payable | Public purpose programs
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	547	559
Total regulatory balancing accounts payable | Other
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	407	394
Total regulatory balancing accounts receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	2,638	2,114
Total regulatory balancing accounts receivable | Electric distribution
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	255	0
Total regulatory balancing accounts receivable | Electric transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	0	9
Total regulatory balancing accounts receivable | Gas distribution and transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	119	363
Total regulatory balancing accounts receivable | Energy procurement
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	1,300	901
Total regulatory balancing accounts receivable | Public purpose programs
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	216	209
Total regulatory balancing accounts receivable | Other
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	$ 748	$ 632

DEBT (Debtor In Possession ("DI

DEBT (Debtor In Possession ("DIP") Facilities and Financing) (Details) - DIP Credit Agreement - Pacific Gas & Electric Co - USD ($) $ in Millions	Jun. 30, 2020	Jan. 29, 2020
DIP Revolving Facility
Line of Credit Facility [Line Items]
Aggregate Limit	$ 5,500
Term Loan Borrowings	2,000
Revolver Borrowings	0
Letters of Credit Outstanding	904
Aggregate Availability	$ 2,596
DIP Delayed Draw Term Loan Facility
Line of Credit Facility [Line Items]
Amount arranged		$ 500

DEBT (Long-term Debt) (Details)

DEBT (Long-term Debt) (Details) - USD ($)	Jul. 01, 2020	Jun. 23, 2020	Jun. 30, 2020	Jun. 19, 2020	May 26, 2020	Dec. 31, 2019
Debt [Line Items]
Restricted cash			$ 14,413,000,000			$ 7,000,000
PG&E Corporation
Debt [Line Items]
Debt instrument, redemption price, percentage		100.00%
Pacific Gas & Electric Co
Debt [Line Items]
Restricted cash			9,076,000,000			$ 7,000,000
Floating Rate First Mortgage Bonds due June 16, 2022 | Pacific Gas & Electric Co
Debt [Line Items]
Debt instrument, face amount				$ 500,000,000
First Mortgage Bonds due June 16, 2022 | Pacific Gas & Electric Co
Debt [Line Items]
Debt instrument, face amount				$ 2,500,000,000
Stated interest rate				1.75%
First Mortgage Bonds due August 1, 2027 | Pacific Gas & Electric Co
Debt [Line Items]
Debt instrument, face amount				$ 1,000,000,000
Stated interest rate				2.10%
First Mortgage Bonds due February 1, 2031 | Pacific Gas & Electric Co
Debt [Line Items]
Debt instrument, face amount				$ 2,000,000,000
Stated interest rate				2.50%
First Mortgage Bonds due August 1, 2040 | Pacific Gas & Electric Co
Debt [Line Items]
Debt instrument, face amount				$ 1,000,000,000
Stated interest rate				3.30%
First Mortgage Bonds due August 1, 2050 | Pacific Gas & Electric Co
Debt [Line Items]
Debt instrument, face amount				$ 1,925,000,000
Stated interest rate				3.50%
New Debt | Pacific Gas & Electric Co
Debt [Line Items]
Restricted cash			8,925,000,000
New Mortgage Bonds | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Debt instrument, face amount	$ 11,900,000,000
Utility Reinstated Senior Notes | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Debt instrument, face amount	9,600,000,000
18-Month Term Loan Facility | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	$ 1,500,000,000
Debt instrument, term	18 months
18-Month Term Loan Facility | Pacific Gas & Electric Co | London Interbank Offered Rate (LIBOR) | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	2.25%
18-Month Term Loan Facility | Pacific Gas & Electric Co | Base Rate | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	1.25%
Term Loan | PG&E Corporation
Debt [Line Items]
Debt instrument, face amount		$ 2,750,000,000
Restricted cash			2,750,000,000
Prepayment premium percentage		1.00%
Term Loan | PG&E Corporation | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Debt instrument, basis spread on variable rate		4.50%
Debt instrument, basis spread on alternative base rate		1.00%
Term Loan | PG&E Corporation | Alternative Base Rate (ABR)
Debt [Line Items]
Debt instrument, basis spread on variable rate		3.50%
Term Loan | PG&E Corporation | Prime Rate
Debt [Line Items]
Debt instrument, basis spread on alternative base rate		0.50%
Term Loan | PG&E Corporation | Minimum | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Debt instrument, basis spread on variable rate		1.00%
Term Loan | PG&E Corporation | Minimum | Alternative Base Rate (ABR)
Debt [Line Items]
Debt instrument, basis spread on variable rate		2.00%
Term Loan | PG&E Corporation | Maximum
Debt [Line Items]
Debt default, amount		$ 200,000,000
Term Loan | Pacific Gas & Electric Co
Debt [Line Items]
Line of credit facility, maximum borrowing capacity					$ 3,000,000,000
Percentage of ownership of outstanding common stock		100.00%
Senior Secured Notes due July 1, 2028 | PG&E Corporation
Debt [Line Items]
Debt instrument, face amount		$ 1,000,000,000
Stated interest rate		5.00%
Senior Secured Notes due July 1, 2030 | PG&E Corporation
Debt [Line Items]
Debt instrument, face amount		$ 1,000,000,000
Stated interest rate		5.25%
Senior Notes | PG&E Corporation
Debt [Line Items]
Restricted cash			$ 2,000,000,000
Debt instrument, redemption price, percentage		40.00%

DEBT (Schedule of Long-term Deb

DEBT (Schedule of Long-term Debt) (Details) - USD ($)	Jul. 01, 2020	Jun. 30, 2020	Dec. 31, 2019
Debt [Line Items]
Pollution control bonds		$ (100,000,000)	$ 0
Debt, net of current portion		34,920,000,000	0
Long-term debt		34,920,000,000
Unamortized discount, net of premium and debt issuance costs		(165,000,000)
Pacific Gas & Electric Co
Debt [Line Items]
Debt		17,525,000,000	17,525,000,000
Pollution control bonds		763,000,000	863,000,000
Debt, net of current portion		30,263,000,000	0
Long-term debt		30,263,000,000
Unamortized discount, net of premium and debt issuance costs		(75,000,000)
Accrued interest			(280,000,000)
Post-petition interest expense			(986,000,000)
PG&E Corporation
Debt [Line Items]
Debt		(650,000,000)	0
Debt		0	650,000,000
Post-petition interest expense			(25,000,000)
PG&E Corporation Revolving Credit Facilities - Stated Maturity: 2022 | PG&E Corporation
Debt [Line Items]
Debt		$ 300,000,000	300,000,000
PG&E Corporation Revolving Credit Facilities - Stated Maturity: 2022 | PG&E Corporation | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Stated interest rate		1.64%
Term Loan - Stated Maturity: 2020 | PG&E Corporation
Debt [Line Items]
Debt		$ 350,000,000	350,000,000
Term Loan - Stated Maturity: 2020 | PG&E Corporation | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Stated interest rate		1.37%
Senior Notes Due 2020 Through 2022 | Pacific Gas & Electric Co
Debt [Line Items]
Debt		$ 1,750,000,000	1,750,000,000
Senior Notes Due 2020 Through 2022 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Stated interest rate		2.45%
Senior Notes Due 2020 Through 2022 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Stated interest rate		4.25%
Senior Notes Due 2023 Through 2028 | Pacific Gas & Electric Co
Debt [Line Items]
Debt		$ 5,025,000,000	5,025,000,000
Senior Notes Due 2023 Through 2028 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Stated interest rate		2.95%
Senior Notes Due 2023 Through 2028 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Stated interest rate		4.65%
Senior Notes Due 2034 Through 2040 | Pacific Gas & Electric Co
Debt [Line Items]
Debt		$ 5,700,000,000	5,700,000,000
Senior Notes Due 2034 Through 2040 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Stated interest rate		5.40%
Senior Notes Due 2034 Through 2040 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Stated interest rate		6.35%
Senior Notes Due 2041 Through 2042 | Pacific Gas & Electric Co
Debt [Line Items]
Debt		$ 1,000,000,000	1,000,000,000
Senior Notes Due 2041 Through 2042 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Stated interest rate		3.75%
Senior Notes Due 2041 Through 2042 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Stated interest rate		4.50%
Senior Notes Due 2043 | Pacific Gas & Electric Co
Debt [Line Items]
Debt		$ 500,000,000	500,000,000
Stated interest rate		5.13%
Senior Notes Due 2043 Through 2047 | Pacific Gas & Electric Co
Debt [Line Items]
Debt		$ 3,550,000,000	3,550,000,000
Senior Notes Due 2043 Through 2047 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Stated interest rate		3.95%
Senior Notes Due 2043 Through 2047 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Stated interest rate		4.75%
Pollution Control Bonds - Series 2008 F and 2010 E, due 2026 | Pacific Gas & Electric Co
Debt [Line Items]
Stated interest rate		1.75%
Pollution control bonds		$ 100,000,000	100,000,000
Pollution Control Bonds - Series 2008 F and 2010 E, due 2026 | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Pollution control bonds	$ 100,000,000
Pollution Control Bonds - Series 2009 A-B, due 2026 | Pacific Gas & Electric Co
Debt [Line Items]
Stated interest rate		6.45%
Pollution control bonds		$ 149,000,000	149,000,000
Pollution Control Bonds - Series 1996 C, E, F, 1997 B due 2026 | Pacific Gas & Electric Co
Debt [Line Items]
Pollution control bonds		$ 614,000,000	614,000,000
Pollution Control Bonds - Series 1996 C, E, F, 1997 B due 2026 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Stated interest rate		6.45%
Pollution Control Bonds - Series 1996 C, E, F, 1997 B due 2026 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Stated interest rate		6.58%
Utility Revolving Credit Facilities - Stated Maturity: 2022 | Pacific Gas & Electric Co
Debt [Line Items]
Debt		$ 2,888,000,000	2,888,000,000
Utility Revolving Credit Facilities - Stated Maturity: 2022 | Pacific Gas & Electric Co | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Stated interest rate		1.44%
Term Loan - Stated Maturity: 2019 | Pacific Gas & Electric Co
Debt [Line Items]
Debt		$ 250,000,000	250,000,000
Term Loan - Stated Maturity: 2019 | Pacific Gas & Electric Co | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Stated interest rate		0.77%
Pre-Petition Credit Facility | Pacific Gas & Electric Co
Debt [Line Items]
Debt		$ 3,138,000,000	3,138,000,000
Term Loan, Stated Maturity 2025 | PG&E Corporation
Debt [Line Items]
Long-term debt, gross		$ 2,750,000,000	0
Term Loan, Stated Maturity 2025 | PG&E Corporation | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Stated interest rate		5.50%
Senior Notes Due 2028 | PG&E Corporation
Debt [Line Items]
Stated interest rate		5.00%
Long-term debt, gross		$ 1,000,000,000	0
Senior Notes Due 2030 | PG&E Corporation
Debt [Line Items]
Stated interest rate		5.25%
Long-term debt, gross		$ 1,000,000,000	0
First Mortgage Bonds, Stated Maturity 2022 | Pacific Gas & Electric Co
Debt [Line Items]
Long-term debt, gross		$ 500,000,000	0
First Mortgage Bonds, Stated Maturity 2022 | Pacific Gas & Electric Co | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Stated interest rate		1.80%
First Mortgage Bonds, Stated Maturity 2022 | Pacific Gas & Electric Co
Debt [Line Items]
Stated interest rate		1.75%
Long-term debt, gross		$ 2,500,000,000	0
First Mortgage Bonds, Stated Maturity 2027 | Pacific Gas & Electric Co
Debt [Line Items]
Stated interest rate		2.10%
Long-term debt, gross		$ 1,000,000,000	0
First Mortgage Bonds, Stated Maturity 2031 | Pacific Gas & Electric Co
Debt [Line Items]
Stated interest rate		2.50%
Long-term debt, gross		$ 2,000,000,000	0
First Mortgage Bonds, Stated Maturity 2040 | Pacific Gas & Electric Co
Debt [Line Items]
Stated interest rate		3.30%
Long-term debt, gross		$ 1,000,000,000	0
First Mortgage Bonds, Stated Maturity 2050 | Pacific Gas & Electric Co
Debt [Line Items]
Stated interest rate		3.50%
Long-term debt, gross		$ 1,925,000,000	0
New Debt
Debt [Line Items]
Long-term debt		13,494,000,000	0
New Debt | Pacific Gas & Electric Co
Debt [Line Items]
Long-term debt		8,837,000,000	0
Unamortized discount, net of premium and debt issuance costs		(88,000,000)	0
New Debt | PG&E Corporation
Debt [Line Items]
Long-term debt		4,657,000,000	0
Unamortized discount, net of premium and debt issuance costs		(93,000,000)	0
First Mortgage Bonds Due 2025 | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Stated interest rate	3.45%
Debt instrument, face amount	$ 875,000,000
First Mortgage Bonds Due 2028 | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Stated interest rate	3.75%
Debt instrument, face amount	$ 875,000,000
First Mortgage Bonds Due 2030 | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Stated interest rate	4.55%
Debt instrument, face amount	$ 3,100,000,000
First Mortgage Bonds Due 2050 | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Stated interest rate	4.95%
Debt instrument, face amount	$ 3,100,000,000
First Mortgage Bonds Due 2026 | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Stated interest rate	3.15%
Debt instrument, face amount	$ 1,950,000,000
First Mortgage Bonds Due 2040 | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Stated interest rate	4.50%
Debt instrument, face amount	$ 1,950,000,000
Pre-Petition Debt
Debt [Line Items]
Long-term debt		21,426,000,000	22,176,000,000
Pre-Petition Debt | Pacific Gas & Electric Co
Debt [Line Items]
Debt, net of current portion		$ 21,426,000,000	$ 21,526,000,000

DEBT (Credit Facility) (Details

DEBT (Credit Facility) (Details)	Jul. 01, 2020USD ($)numberOfExtensionOption	Jun. 23, 2020USD ($)	May 26, 2020USD ($)numberOfExtensionOptionnumberOfTranche	Jul. 31, 2020
Revolving Credit Facility | PG&E Corporation
Debt [Line Items]
Line of credit facility, maximum borrowing capacity			$ 500,000,000
Debt instrument, term			3 years
Debt, number of extension options | numberOfExtensionOption			2
Debt instrument, extension option, term			1 year
Revolving Credit Facility | Pacific Gas & Electric Co
Debt [Line Items]
Line of credit facility, maximum borrowing capacity			$ 3,500,000,000
Debt instrument, term			3 years
Debt, number of extension options | numberOfExtensionOption			2
Debt instrument, extension option, term			1 year
Term Loan | PG&E Corporation | Subsequent event
Debt [Line Items]
Repayments of debt	$ 350,000,000
Term Loan | PG&E Corporation | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Debt instrument, basis spread on variable rate		4.50%
Term Loan | PG&E Corporation | Minimum | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Debt instrument, basis spread on variable rate		1.00%
Term Loan | PG&E Corporation | Maximum
Debt [Line Items]
Debt default, amount		$ 200,000,000
Term Loan | Pacific Gas & Electric Co
Debt [Line Items]
Line of credit facility, maximum borrowing capacity			$ 3,000,000,000
Debt, number of tranches | numberOfTranche			2
Percentage of ownership of outstanding common stock		100.00%
Term Loan, 1 | Pacific Gas & Electric Co
Debt [Line Items]
Debt instrument, term			364 days
Term Loan, 2 | Pacific Gas & Electric Co
Debt [Line Items]
Debt instrument, term			18 months
Revolving Credit Agreement | PG&E Corporation | Subsequent event
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	$ 500,000,000
Debt, number of extension options | numberOfExtensionOption	2
Debt instrument, extension option, term	1 year
Percentage of ownership of outstanding common stock	100.00%
Revolving Credit Agreement | PG&E Corporation | Minimum | Subsequent event
Debt [Line Items]
Commitment fee percentage	0.50%
Debt, ratio of total consolidated debt to consolidated capitalization, loans outstanding balance	150.00%
Debt, ratio of total consolidated debt to consolidated capitalization, cash dividend declared	100.00%
Revolving Credit Agreement | PG&E Corporation | Minimum | London Interbank Offered Rate (LIBOR) | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	3.00%
Revolving Credit Agreement | PG&E Corporation | Minimum | Base Rate | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	2.00%
Revolving Credit Agreement | PG&E Corporation | Maximum | Subsequent event
Debt [Line Items]
Commitment fee percentage	0.75%
Debt, ratio of total consolidated debt to consolidated capitalization	70.00%
Debt default, amount	$ 200,000,000
Revolving Credit Agreement | PG&E Corporation | Maximum | London Interbank Offered Rate (LIBOR) | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	4.25%
Revolving Credit Agreement | PG&E Corporation | Maximum | Base Rate | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	3.25%
Revolving Credit Agreement | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	$ 3,500,000,000
Debt instrument, term	3 years
Debt, number of extension options | numberOfExtensionOption	2
Debt instrument, extension option, term				1 year
Letter of credit, maximum borrowing capacity	$ 1,500,000,000
Revolving Credit Agreement | Pacific Gas & Electric Co | Minimum | Subsequent event
Debt [Line Items]
Commitment fee percentage	0.25%
Revolving Credit Agreement | Pacific Gas & Electric Co | Minimum | London Interbank Offered Rate (LIBOR) | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	1.375%
Revolving Credit Agreement | Pacific Gas & Electric Co | Minimum | Base Rate | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	0.375%
Revolving Credit Agreement | Pacific Gas & Electric Co | Maximum | Subsequent event
Debt [Line Items]
Commitment fee percentage	0.50%
Debt, ratio of total consolidated debt to consolidated capitalization	65.00%
Debt default, amount	$ 200,000,000
Revolving Credit Agreement | Pacific Gas & Electric Co | Maximum | London Interbank Offered Rate (LIBOR) | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	2.50%
Revolving Credit Agreement | Pacific Gas & Electric Co | Maximum | Base Rate | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	1.50%
Term Loan Credit Agreement | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	$ 3,000,000,000
Debt, percentage of net cash proceeds from certain securitization transactions prepayment	100.00%
Term Loan Credit Agreement | Pacific Gas & Electric Co | Maximum | Subsequent event
Debt [Line Items]
Debt, ratio of total consolidated debt to consolidated capitalization	65.00%
Debt default, amount	$ 200,000,000
364-Day Term Loan Facility | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	$ 1,500,000,000
Debt instrument, term	364 days
364-Day Term Loan Facility | Pacific Gas & Electric Co | London Interbank Offered Rate (LIBOR) | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	2.00%
364-Day Term Loan Facility | Pacific Gas & Electric Co | Base Rate | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	1.00%
18-Month Term Loan Facility | Pacific Gas & Electric Co | Subsequent event
Debt [Line Items]
Line of credit facility, maximum borrowing capacity	$ 1,500,000,000
Debt instrument, term	18 months
18-Month Term Loan Facility | Pacific Gas & Electric Co | London Interbank Offered Rate (LIBOR) | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	2.25%
18-Month Term Loan Facility | Pacific Gas & Electric Co | Base Rate | Subsequent event
Debt [Line Items]
Debt instrument, basis spread on variable rate	1.25%
Second Amended and Restated Credit Agreement | PG&E Corporation | Subsequent event
Debt [Line Items]
Repayments of debt	$ 300,000,000

EQUITY (Details)

EQUITY (Details) $ / shares in Units, purchaseContract in Thousands, equityUnit in Thousands, $ in Millions	Aug. 03, 2020equityUnitshares	Jul. 01, 2020USD ($)shares	Jun. 25, 2020USD ($)purchaseContractequityUnitshares	Jun. 07, 2020USD ($)$ / shares	Jul. 31, 2020USD ($)	Jun. 30, 2020USD ($)shares	Jun. 30, 2020USD ($)shares	Jun. 22, 2020shares	Mar. 20, 2020USD ($)	Dec. 31, 2019USD ($)shares
Schedule Of Changes In Equity [Line Items]
Common stock, shares authorized (in shares)						3,600,000,000	3,600,000,000	3,600,000,000		800,000,000
Preferred stock, shares authorized (in shares)								400,000,000
Proceeds through the issuance of common stock and other equity-linked instruments | $			$ 3,970
Sale of stock, consideration received on transaction | $				$ 3,250
Sale of stock, price per share (in dollar per share) | $ / shares				$ 9.50
Proceeds from issuance or sale of equity, net | $			$ 1,190
Proceeds from equity backstop commitments and forward stock purchase agreements | $							$ 523
Equity contribution cash | $						$ 12,900	$ 12,900
Percentage of equity security ownership with board of director approval						4.75%	4.75%
Dividend reinstatement target, amount | $									$ 6,200
Fire Trust Victim
Schedule Of Changes In Equity [Line Items]
Litigation liability, payment accrual | $										$ 6,750
Deferred tax asset, litigation adjustment | $						$ 619
Subsequent event
Schedule Of Changes In Equity [Line Items]
Proceeds through the issuance of common stock and other equity-linked instruments | $		$ 9,000			$ 9,000
Sale of stock, number of shares issued in transaction (in shares)		342,100,000
Proceeds from issuance or sale of equity, net | $		$ 5,200
Transfer of shares to Fire Victim Trust (in shares)		477,000,000
Option to purchase additional contracts (in equity units) | equityUnit	1,450
Transfer of shares to Fire Victim Trust, additional (in shares)	748,415
Subsequent event | Fire Trust Victim
Schedule Of Changes In Equity [Line Items]
Transfer of shares to Fire Victim Trust (in shares)		477,000,000
Option to purchase additional contracts (in equity units) | equityUnit	1,450
Transfer of shares to Fire Victim Trust, additional (in shares)	748,415
Transfer of shares related to litigation settlement, value | $		$ 4,530
Difference between payment accrual and transfer of shares related to litigation settlement, value | $		$ 2,220
Subsequent event | Minimum | PG&E Corporation | Revolving Credit Agreement
Schedule Of Changes In Equity [Line Items]
Debt, ratio of total consolidated debt to consolidated capitalization, loans outstanding balance		150.00%
Debt, ratio of total consolidated debt to consolidated capitalization, cash dividend declared		100.00%
Subsequent event | Maximum | PG&E Corporation | Revolving Credit Agreement
Schedule Of Changes In Equity [Line Items]
Debt, ratio of total consolidated debt to consolidated capitalization		70.00%
Common Stock Offering
Schedule Of Changes In Equity [Line Items]
Sale of stock, number of shares issued in transaction (in shares)			423,400,000
Option to purchase additional stock (in shares)			42,300,000
Common Stock Underwriters
Schedule Of Changes In Equity [Line Items]
Sale of stock, number of shares issued and sold in transaction (in shares)			423,400,000
Equity Units Offering
Schedule Of Changes In Equity [Line Items]
Sale of stock, number of equity units issued in transaction (in equity units) | equityUnit			14,500
Sale of stock, number of prepaid forward stock purchase contracts issued and sold in transaction (in purchase contracts) | purchaseContract			14,500
Sale of stock, number of prepaid forward stock purchase contracts issued and sold in transaction, additional contracts (in purchase contracts) | purchaseContract			1,450
Sale of stock, number of equity units issued in transaction, additional (in equity units) | equityUnit			1,450
Equity Units Offering | Minimum
Schedule Of Changes In Equity [Line Items]
Right to receive (in shares)			125,000,000
Equity Units Offering | Maximum
Schedule Of Changes In Equity [Line Items]
Right to receive (in shares)			153,000,000
Equity Units Offering | Subsequent event
Schedule Of Changes In Equity [Line Items]
Sale of stock, number of equity units issued in transaction, additional (in equity units) | equityUnit	1,450
Equity Units Underwriters
Schedule Of Changes In Equity [Line Items]
Sale of stock, number of prepaid forward stock purchase contracts issued and sold in transaction (in purchase contracts) | purchaseContract			14,500
February 2017 Equity Distribution Agreement
Schedule Of Changes In Equity [Line Items]
Common stock issued (in shares)						0	0

EARNINGS PER SHARE (Details)

EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Earnings Per Share [Abstract]
Loss attributable to common shareholders	$ (1,972)	$ (2,553)	$ (1,601)	$ (2,420)
Weighted average common shares outstanding, basic (in shares)	529	529	529	528
Add incremental shares from assumed conversions:
Employee share-based compensation (in shares)	0	0	0	0
Weighted average common shares outstanding, diluted (in shares)	529	529	529	528
Total loss per common share, diluted (in dollars per share)	$ (3.73)	$ (4.83)	$ (3.03)	$ (4.58)

DERIVATIVES (Volumes of Outstan

DERIVATIVES (Volumes of Outstanding Derivative Contracts, in Megawatt Hours Unless Otherwise Specified) (Details)	Jun. 30, 2020MMBTUMWh	Dec. 31, 2019MWhMMBTU
Forwards, Futures and Swaps | Natural Gas
Derivative [Line Items]
Contract Volume (mmbtu and mwh) | MMBTU	199,547,057	131,896,159
Forwards, Futures and Swaps | Electricity
Derivative [Line Items]
Contract Volume (mmbtu and mwh)	9,754,771	18,675,852
Options | Natural Gas
Derivative [Line Items]
Contract Volume (mmbtu and mwh) | MMBTU	33,810,000	14,720,000
Options | Electricity
Derivative [Line Items]
Contract Volume (mmbtu and mwh)	1,620,000	0
Congestion Revenue Rights | Electricity
Derivative [Line Items]
Contract Volume (mmbtu and mwh)	287,183,280	308,467,999

DERIVATIVES (Outstanding Deriva

DERIVATIVES (Outstanding Derivative Balances) (Details) - Commodity Risk - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	$ (60)	$ 5
Derivative Asset, Netting	0	0
Cash Collateral	29	6
Total Derivative Balance, Assets	(31)	11
Current assets – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	46	36
Derivative Asset, Netting	(7)	(6)
Cash Collateral	29	4
Total Derivative Balance, Assets	68	34
Other noncurrent assets – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	121	130
Derivative Asset, Netting	0	(6)
Cash Collateral	0	0
Total Derivative Balance, Assets	121	124
Current liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Liabilities	(44)	(31)
Derivative Liability, Netting	7	6
Cash Collateral	0	2
Total Derivative Balance, Liabilities	(37)	(23)
Noncurrent liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Liabilities	(183)	(130)
Derivative Liability, Netting	0	6
Cash Collateral	0	0
Total Derivative Balance, Liabilities	$ (183)	$ (124)

FAIR VALUE MEASUREMENTS (Assets

FAIR VALUE MEASUREMENTS (Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Assets:
Short-term investments	$ 718	$ 1,323
Price risk management instruments, netting	22	(8)
Price risk management instruments, assets	189	158
TOTAL ASSETS	4,981	5,523
Liabilities:
Price risk management instruments, netting	(7)	(14)
TOTAL LIABILITIES	1,720	147
Amount primarily related to deferred taxes on appreciation of investment value	540	530
Nuclear decommissioning trusts
Assets:
Short-term investments	34	6
Global equity securities	2,135	2,086
Fixed-income securities	1,547	1,590
TOTAL ASSETS	3,736	3,703
Rabbi trusts
Assets:
Fixed-income securities	105	100
Life insurance contracts	77	73
TOTAL ASSETS	182	173
Long-term disability trust
Assets:
Short-term investments	6	10
TOTAL ASSETS	156	166
Equity Backstop Commitments and Forward Stock Purchase Agreements
Liabilities:
Derivative liability	1,500
Price Risk Derivative, Electricity
Assets:
Price risk management instruments, netting	21	(11)
Price risk management instruments, assets	183	152
Liabilities:
Price risk management instruments, netting	(6)	(13)
Price risk management instruments, liabilities	217	146
Price Risk Derivative, Gas
Assets:
Price risk management instruments, netting	1	3
Price risk management instruments, assets	6	6
Liabilities:
Price risk management instruments, netting	(1)	(1)
Price risk management instruments, liabilities	3	1
Level 1
Assets:
Short-term investments	718	1,323
Price risk management instruments, gross subject to netting	0	0
TOTAL ASSETS	3,687	4,287
Liabilities:
TOTAL LIABILITIES	0	1
Level 1 | Nuclear decommissioning trusts
Assets:
Short-term investments	34	6
Global equity securities	2,135	2,086
Fixed-income securities	794	862
TOTAL ASSETS	2,963	2,954
Level 1 | Rabbi trusts
Assets:
Fixed-income securities	0	0
Life insurance contracts	0	0
TOTAL ASSETS	0	0
Level 1 | Long-term disability trust
Assets:
Short-term investments	6	10
TOTAL ASSETS	6	10
Level 1 | Equity Backstop Commitments and Forward Stock Purchase Agreements
Liabilities:
Derivative liability	0
Level 1 | Price Risk Derivative, Electricity
Assets:
Price risk management instruments, gross subject to netting	0	0
Liabilities:
Price risk management instruments, gross subject to netting	0	1
Level 1 | Price Risk Derivative, Gas
Assets:
Price risk management instruments, gross subject to netting	0	0
Liabilities:
Price risk management instruments, gross subject to netting	0	0
Level 2
Assets:
Short-term investments	0	0
Price risk management instruments, gross subject to netting	19	5
TOTAL ASSETS	954	906
Liabilities:
TOTAL LIABILITIES	1,513	4
Level 2 | Nuclear decommissioning trusts
Assets:
Short-term investments	0	0
Global equity securities	0	0
Fixed-income securities	753	728
TOTAL ASSETS	753	728
Level 2 | Rabbi trusts
Assets:
Fixed-income securities	105	100
Life insurance contracts	77	73
TOTAL ASSETS	182	173
Level 2 | Long-term disability trust
Assets:
Short-term investments	0	0
TOTAL ASSETS	0	0
Level 2 | Equity Backstop Commitments and Forward Stock Purchase Agreements
Liabilities:
Derivative liability	1,500
Level 2 | Price Risk Derivative, Electricity
Assets:
Price risk management instruments, gross subject to netting	14	2
Liabilities:
Price risk management instruments, gross subject to netting	9	2
Level 2 | Price Risk Derivative, Gas
Assets:
Price risk management instruments, gross subject to netting	5	3
Liabilities:
Price risk management instruments, gross subject to netting	4	2
Level 3
Assets:
Short-term investments	0	0
Price risk management instruments, gross subject to netting	148	161
TOTAL ASSETS	148	161
Liabilities:
TOTAL LIABILITIES	214	156
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 | Rabbi trusts
Assets:
Fixed-income securities	0	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 | Equity Backstop Commitments and Forward Stock Purchase Agreements
Liabilities:
Derivative liability	0
Level 3 | Price Risk Derivative, Electricity
Assets:
Price risk management instruments, gross subject to netting	148	161
Liabilities:
Price risk management instruments, gross subject to netting	214	156
Level 3 | Price Risk Derivative, Gas
Assets:
Price risk management instruments, gross subject to netting	0	0
Liabilities:
Price risk management instruments, gross subject to netting	0	0
Assets measured at NAV | Nuclear decommissioning trusts
Assets:
Assets measured at NAV	20	21
Assets measured at NAV | Long-term disability trust
Assets:
Assets measured at NAV	$ 150	$ 156

FAIR VALUE MEASUREMENTS (Equity

FAIR VALUE MEASUREMENTS (Equity Backstop Commitments and Forward Stock Purchase Agreements) (Details) $ in Millions	Jun. 30, 2020USD ($)
Fair Value Disclosures [Abstract]
Backstop commitment premium, expense	$ 1,100
Additional backstop commitment premium, expense	$ 444

FAIR VALUE MEASUREMENTS (Level

FAIR VALUE MEASUREMENTS (Level 3 Measurements and Sensitivity Analysis) (Details) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2020USD ($)$ / MWh	Dec. 31, 2019USD ($)$ / MWh
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets | $	$ 4,981	$ 5,523
Liabilities | $	1,720	147
Market approach | Congestion revenue rights
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets | $	135	140
Liabilities | $	$ 59	$ 44
Market approach | Congestion revenue rights | Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unobservable input (dollars per mwh) | $ / MWh	(23.93)	(20.20)
Market approach | Congestion revenue rights | Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unobservable input (dollars per mwh) | $ / MWh	25.51	20.20
Market approach | Congestion revenue rights | Weighted Average Price
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unobservable input (dollars per mwh) | $ / MWh	0.27	0.28
Discounted cash flow | Power purchase agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets | $	$ 13	$ 21
Liabilities | $	$ 155	$ 112
Discounted cash flow | Power purchase agreements | Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unobservable input (dollars per mwh) | $ / MWh	11.83	11.77
Discounted cash flow | Power purchase agreements | Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unobservable input (dollars per mwh) | $ / MWh	64.30	59.38
Discounted cash flow | Power purchase agreements | Weighted Average Price
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unobservable input (dollars per mwh) | $ / MWh	31.81	33.62

FAIR VALUE MEASUREMENTS (Leve_2

FAIR VALUE MEASUREMENTS (Level 3 Reconciliation) (Details) - Level 3 - Price Risk Management Instruments - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning asset (liability) balance	$ (5)	$ 129	$ 5	$ 95
Net Realized and Unrealized Gains (Losses) [Abstract]
Included in regulatory assets and liabilities or balancing accounts	(61)	(20)	(71)	14
Ending asset (liability) balance	$ (66)	$ 109	$ (66)	$ 109

FAIR VALUE MEASUREMENTS (Carryi

FAIR VALUE MEASUREMENTS (Carrying Amount and Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 34,920
Utility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	30,263
Fair value disclosure, pre-petition debt		$ 17,900
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	2,257	0
Carrying Amount | Utility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	25,962	1,500
Fair Value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	2,005	0
Fair Value | Utility | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 28,853	$ 1,500

FAIR VALUE MEASUREMENTS (Schedu

FAIR VALUE MEASUREMENTS (Schedule of Unrealized Gains (Losses) Related to Available-for-Sale Investments) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	$ 2,066	$ 2,011
Total Unrealized Gains	1,689	1,698
Total Unrealized Losses	(19)	(6)
Total Fair Value	3,736	3,703
Amount primarily related to deferred taxes on appreciation of investment value	540	530
Short-term investments
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	34	6
Total Unrealized Gains	0	0
Total Unrealized Losses	0	0
Total Fair Value	34	6
Global equity securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	646	500
Total Unrealized Gains	1,524	1,609
Total Unrealized Losses	(15)	(2)
Total Fair Value	2,155	2,107
Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	1,386	1,505
Total Unrealized Gains	165	89
Total Unrealized Losses	(4)	(4)
Total Fair Value	$ 1,547	$ 1,590

FAIR VALUE MEASUREMENTS (Sche_2

FAIR VALUE MEASUREMENTS (Schedule of Maturities on Debt Securities) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Debt Securities, Available-for-sale [Line Items]
Total fair value	$ 3,736	$ 3,703
Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Less than 1 year	28
1–5 years	416
5–10 years	404
More than 10 years	699
Total fair value	$ 1,547	$ 1,590

FAIR VALUE MEASUREMENTS (Sche_3

FAIR VALUE MEASUREMENTS (Schedule of Activity for Debt and Equity Securities) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Fair Value Disclosures [Abstract]
Proceeds from sales and maturities of nuclear decommissioning trust investments	$ 254	$ 171	$ 787	$ 517
Gross realized gains on securities	8	56	26	22
Gross realized losses on securities	$ (12)	$ (26)	$ (21)	$ (7)

WILDFIRE-RELATED CONTINGENCIE_2

WILDFIRE-RELATED CONTINGENCIES (2018 Camp Fire and 2017 Northern California Wildfires Background) (Details) $ in Millions	Apr. 21, 2020USD ($)	Nov. 08, 2018abuildingfatality	Oct. 30, 2017awildfirestructurefatality
Fire Victim Trust
Loss Contingencies [Line Items]
Claim	$ 115.3
Claim payment, initial	70
Claim payment, remaining	45.3
Proceeds from common stock	60
Common stock in excess	6,750
Fire Victim Trust | Federal Agencies
Loss Contingencies [Line Items]
Tentative agreement	1,000
Fire Victim Trust | Department of Justice
Loss Contingencies [Line Items]
Agreement payment	117
Fire Victim Trust | Other State Agencies
Loss Contingencies [Line Items]
Tentative agreement	$ 89
Pacific Gas & Electric Co | 2018 Camp Fire
Loss Contingencies [Line Items]
Number of acres burned (acre) | a		153,336
Number of fatalities (fatality) | fatality		85
Number of other buildings destroyed (structures) | building		18,804
Pacific Gas & Electric Co | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Number of acres burned (acre) | a			245,000
Number of fatalities (fatality) | fatality			44
Number of wildfires (wildfire) | wildfire			21
Number of structures destroyed (structure) | structure			8,900

WILDFIRE-RELATED CONTINGENCIE_3

WILDFIRE-RELATED CONTINGENCIES (Pre-petition Wildfire-Related Claims and Discharge Upon Plan Effective Date) (Details) - USD ($) shares in Millions, $ in Millions	Jul. 01, 2020	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019	Sep. 22, 2019
Loss Contingencies [Line Items]
Wildfire-related claims		$ 25,500		$ 25,500
Accrued environmental loss contingencies, current, elimination		12,150
Subrogation claims, professional fees							$ 55
Subsequent event
Loss Contingencies [Line Items]
Transfer of shares to Fire Victim Trust (in shares)	477
Plan of reorganization, tax benefits payment agreement	$ 1,350
Subsequent event | Settling Public Entities
Loss Contingencies [Line Items]
Litigation payment	1,000
Litigation, segregated reimbursement fund	10
Fire Victim Trust | Subsequent event
Loss Contingencies [Line Items]
Litigation payment, fund, cash	5,400
Litigation payment, additional funded, deferred	$ 1,350
Transfer of shares to Fire Victim Trust (in shares)	477
Percentage of common stock owned, Fire Victim Trust if common issues additional shares	22.19%
Subrogation Wildfire Trust | Subsequent event
Loss Contingencies [Line Items]
Litigation payment, fund, cash	$ 11,000
Litigation payment	43
Subrogation claims, professional fees	$ 52
2019 Kincade Fire
Loss Contingencies [Line Items]
Legal fees		2		2
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Wildfire-related claims		25,500		25,500		$ 25,500
Subrogation insurance claims		11,000		11,000
Subrogation claims, expected professional fees		47.5		47.5
Subrogation claims, professional fees		52		52
Professional fees extinguished				47.5
Legal fees		24	$ 26	58	$ 73
Pacific Gas & Electric Co | Public Entity Wildfire Claims
Loss Contingencies [Line Items]
Wildfire-related claims		1,000		1,000
Pacific Gas & Electric Co | Public Entity Wildfire Claims | Settling Public Entities
Loss Contingencies [Line Items]
Wildfire-related claims		1,000		1,000
Pacific Gas & Electric Co | All Other Wildfire-related Claims
Loss Contingencies [Line Items]
Wildfire-related claims		$ 13,500		$ 13,500

WILDFIRE-RELATED CONTINGENCIE_4

WILDFIRE-RELATED CONTINGENCIES (Plan Support Agreements with Public Entities) (Details) - Public Entity Wildfire Claims - Settled Litigation $ in Millions	Jun. 18, 2019USD ($)
Loss Contingencies [Line Items]
Settlement reached	$ 1,000
Fund to support defense or resolution of claims for each PSA	$ 10

WILDFIRE- RELATED CONTINGENCIES

WILDFIRE- RELATED CONTINGENCIES (Restructuring Support Agreement) (Details) $ in Millions	Sep. 22, 2019USD ($)	Jul. 01, 2020	Jun. 30, 2020USD ($)	Dec. 06, 2019USD ($)
Loss Contingencies [Line Items]
TCC claims settlement, amount	$ 11,000
Subrogation claims, professional fees	$ 55
Fire Victim Trust | Subsequent event
Loss Contingencies [Line Items]
Percentage of common stock owned, Fire Victim Trust if common issues additional shares		22.19%
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Subrogation claims, professional fees			$ 52
Cash				$ 1,350
Multiplier, normalized estimated net income				14.9
Number of fully diluted shares of the reorganized, perent				20.90%
Pacific Gas & Electric Co | Effective Date
Loss Contingencies [Line Items]
Cash contribution by company				$ 5,400
Pacific Gas & Electric Co | On Or Before January 15, 2021
Loss Contingencies [Line Items]
Cash				650
Pacific Gas & Electric Co | On Or Before January 15, 2022
Loss Contingencies [Line Items]
Cash				$ 1,350

WILDFIRE-RELATED CONTINGENCIE_5

WILDFIRE-RELATED CONTINGENCIES (2019 Kincade Fire) (Details) $ in Millions	Nov. 04, 2019numberOfPeople	Jun. 30, 2020USD ($)	Jul. 31, 2020USD ($)	Jul. 27, 2020numberOfComplaintplaintiff	Oct. 23, 2019anumberOfStructureinjurycustomerstructurefacility
2019 Kincade Fire
Loss Contingencies [Line Items]
Number of acres burned (acre) | a					77,758
Number of fatalities (fatality) | facility					0
Number of injuries | injury					4
Number of structures destroyed (structure) | structure					374
Number of residences destroyed (residence)					174
Number of commercial structures destroyed (structure)					11
Number of other buildings destroyed (structures)					189
Number of structures damaged (structure)					60
Number of residential structures damaged (structure)					35
Number of commercial structures damaged (structure)					1
Number of other structures damaged (structure)					24
Number of people part of mandatory evacuation order | numberOfPeople	200,000
Number of customers without power | customer					27,837
Potential loss contingency | $		$ 600
Loss contingency, claim eligibility requirement amount | $		1,000
2019 Kincade Fire | Subsequent event
Loss Contingencies [Line Items]
Number of group complaint | numberOfComplaint				3
Number of plaintiffs represented by group complaints | plaintiff				142
Insurance Coverage for Wildfire Events
Loss Contingencies [Line Items]
Liability insurance coverage | $		$ 430
Insurance Coverage for Wildfire Events | Subsequent event
Loss Contingencies [Line Items]
Liability insurance coverage | $			$ 757.5

WILDFIRE-RELATED CONTINGENCIE_6

WILDFIRE-RELATED CONTINGENCIES (Insurance) (Details) - USD ($) $ in Millions	Jul. 01, 2020	Jun. 30, 2020	Jul. 31, 2020
Insurance Coverage For Wildfire and Non-Wildfire Events | Subsequent event
Loss Contingencies [Line Items]
Costs for insurance coverage	$ 749
Insurance Coverage For Wildfire and Non-Wildfire Events | August 1, 2019 - September 2, 2020
Loss Contingencies [Line Items]
Costs for insurance coverage		$ 212
Insurance Coverage for Wildfire Events
Loss Contingencies [Line Items]
Liability insurance coverage		430
Initial self-insured retention per occurrence		10
Insurance Coverage for Wildfire Events | Subsequent event
Loss Contingencies [Line Items]
Liability insurance coverage			$ 757.5
Initial self-insured retention per occurrence			60
Insurance Coverage for Wildfire Events | August 1, 2020 - July 31, 2021 | Subsequent event
Loss Contingencies [Line Items]
Liability insurance coverage			715
Insurance Coverage for Wildfire Events | July 1, 2020 - June 30, 2021 | Subsequent event
Loss Contingencies [Line Items]
Reinsurance			42.5
Insurance Coverage For Non-Wildfire Events
Loss Contingencies [Line Items]
Liability insurance coverage		1,000
Initial self-insured retention per occurrence		10
Insurance Coverage For Non-Wildfire Events | August 1, 2019 - July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage		520
Insurance Coverage For Non-Wildfire Events | September 3, 2019 - September 2, 2020
Loss Contingencies [Line Items]
Liability insurance coverage		480
Insurance Coverage For Non-Wildfire Events | August 1, 2020 - July 31, 2021 | Subsequent event
Loss Contingencies [Line Items]
Liability insurance coverage			700
Initial self-insured retention per occurrence			$ 10
2018 Camp Fire
Loss Contingencies [Line Items]
Estimated insurance recoveries		1,380
2017 Northern California wildfires
Loss Contingencies [Line Items]
Estimated insurance recoveries		$ 843

WILDFIRE-RELATED CONTINGENCIE_7

WILDFIRE-RELATED CONTINGENCIES (Insurance Receivable) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	$ 2,237
Accrued insurance recoveries	430
Reimbursements	(529)
Insurance Receivable, Ending Balance	2,138
2019 Kincade Fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	0
Accrued insurance recoveries	430
Reimbursements	0
Insurance Receivable, Ending Balance	430
2018 Camp Fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	1,380
Accrued insurance recoveries	0
Reimbursements	(408)
Insurance Receivable, Ending Balance	972
2017 Northern California wildfires
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	807
Accrued insurance recoveries	0
Reimbursements	(121)
Insurance Receivable, Ending Balance	686
Butte Fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	50
Accrued insurance recoveries	0
Reimbursements	0
Insurance Receivable, Ending Balance	$ 50

WILDFIRE-RELATED CONTINGENCIE_8

WILDFIRE-RELATED CONTINGENCIES (Regulatory Recovery) (Details) - 2018 Camp Fire and 2017 Northern California Wildfires - USD ($) $ in Millions	Apr. 30, 2020	Jul. 08, 2019
Loss Contingencies [Line Items]
Customer Harm Threshold, potential regulatory adjustment, percentage		20.00%
Customer Harm Threshold, potential regulatory adjustment, percentage of total disallowed wildlife liability		5.00%
Customer Harm Threshold, post-emergence transaction, securitized	$ 7,500
Customer Harm Threshold, post-emergence transaction, debt retirement	6,000
Customer Harm Threshold, post-emergence transaction, debt payment acceleration	$ 700

WILDFIRE-RELATED CONTINGENCIE_9

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

WILDFIRE-RELATED CONTINGENCI_10

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

WILDFIRE-RELATED CONTINGENCI_11

WILDFIRE-RELATED CONTINGENCIES (District Attorneys Offices Investigations) (Details) $ in Millions	Jul. 21, 2020USD ($)	Mar. 17, 2020USD ($)count	Jun. 30, 2020USD ($)	Jun. 30, 2019USD ($)	Jun. 30, 2020USD ($)	Jun. 30, 2019USD ($)
Loss Contingencies [Line Items]
Settlement expense			$ 173	$ 0	$ 173	$ 0
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Settlement expense			$ 173	$ 0	$ 173	$ 0
Pacific Gas & Electric Co | Complaints Brought By Butte County District Attorney | Loss from Wildfires
Loss Contingencies [Line Items]
Number of Guilty Involuntary Manslaughter Pleas | count		84
Settlement expense		$ 3.5
Reimbursement of investigation fees		0.5
Committed funds for impacted residence		$ 15
Committed funds for impacted residence, minimum term		5 years
Pacific Gas & Electric Co | Complaints Brought By Butte County District Attorney | Loss from Wildfires | Subsequent event
Loss Contingencies [Line Items]
Settlement expense	$ 3.5
Reimbursement of investigation fees	$ 0.5

WILDFIRE-RELATED CONTINGENCI_12

WILDFIRE-RELATED CONTINGENCIES (Clean-up and Repair Costs) (Details) - USD ($)	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Loss Contingencies [Line Items]
Capital expenditures	$ 273,000,000	$ 836,000,000
Total long-term regulatory assets	7,507,000,000		$ 6,066,000,000
Catastrophic event memorandum account
Loss Contingencies [Line Items]
Total long-term regulatory assets	646,000,000		656,000,000
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Capital expenditures	273,000,000	$ 836,000,000
Total long-term regulatory assets	7,507,000,000		$ 6,066,000,000
Pacific Gas & Electric Co | 2018 Camp Fire
Loss Contingencies [Line Items]
Service restoration and repair costs	826,000,000
Capital expenditures	358,000,000
Pacific Gas & Electric Co | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Service restoration and repair costs	349,000,000
Capital expenditures	193,000,000
Pacific Gas & Electric Co | 2019 Kincade Fire
Loss Contingencies [Line Items]
Service restoration and repair costs	62,000,000
Capital expenditures	18,000,000
Pacific Gas & Electric Co | Catastrophic event memorandum account | 2018 Camp Fire
Loss Contingencies [Line Items]
Total long-term regulatory assets	0
Pacific Gas & Electric Co | Catastrophic event memorandum account | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Total long-term regulatory assets	49,000,000
Pacific Gas & Electric Co | Catastrophic event memorandum account | 2019 Kincade Fire
Loss Contingencies [Line Items]
Total long-term regulatory assets	$ 0

WILDFIRE-RELATED CONTINGENCI_13

WILDFIRE-RELATED CONTINGENCIES (Wildfire Fund) (Details) - USD ($) $ in Millions	Aug. 23, 2019	Jul. 12, 2020	Jun. 30, 2020	Aug. 02, 2019	Jul. 12, 2019
Loss Contingencies [Line Items]
Wildfire-related claims			$ 25,500
Disallowance cap, transmission and distribution equity rate base					$ 2,400
Initial safety certification, period	12 months
Initial safety certification, documentation provided, period	90 days
Expected capitalization, proceeds of bond	$ 10,500
Expected capitalization, initial contribution	7,500
Expected capitalization, annual contribution	$ 300
Expected wildfire fund allocation metric, percentage	64.20%
Expected wildfire fund allocation metric, initial contribution	$ 4,800
Expected wildfire fund allocation metric, annual contributions	193
Expected wildfire fund allocation metric, initial capital expenditure	5,000
Allocation	$ 3,210
Initial contribution payment			4,800
Annual contribution, first payment			193
Subsequent event
Loss Contingencies [Line Items]
Percentage of claim limit		40.00%
2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Wildfire-related claims				$ 105
Claimant payments			$ 100

OTHER CONTINGENCIES AND COMMI_3

OTHER CONTINGENCIES AND COMMITMENTS (Order Instituting Investigation Narrative) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)	Jun. 08, 2020party	Apr. 20, 2020USD ($)	Dec. 17, 2019USD ($)
Loss Contingencies [Line Items]
Expenses and capital expenditures, disallowed capital, gross	$ 348
Expenses and capital expenditures, disallowed capital, net	403
Expenses and capital expenditures, disallowed capital, expected charges to be recorded	34
Expenses and capital expenditures, disallowed capital, approved			$ 198
Shareholder-funded system enhancement initiatives, approved			64
Fine payable to general fund, suspended			$ 200
Number of parties filed separate applications for rehearing | party		2
Pacific Gas & Electric Co | Vegetation Management Support Costs (FHPMA)
Loss Contingencies [Line Items]
Expenses and capital expenditures	36
Expenses and capital expenditures, disallowed capital, expected charges to be recorded	6
Expenses and capital expenditures, disallowed capital, charges recorded	84
Pacific Gas & Electric Co | Pending Litigation | Unfavorable Regulatory Action
Loss Contingencies [Line Items]
Expenses and capital expenditures	1,625			$ 1,625
Shareholder-funded system enhancement initiatives, amount				$ 50
Expenses and capital expenditures, difference	$ 1,420

OTHER CONTINGENCIES AND COMMI_4

OTHER CONTINGENCIES AND COMMITMENTS (Order Instituting Investigation Legal Obligation) (Details) - Pacific Gas & Electric Co $ in Millions	Jun. 30, 2020USD ($)
Loss Contingencies [Line Items]
Expense	$ 1,222
Capital	403
Expenses and capital expenditures, forecast	1,625
Distribution Safety Inspections and Repairs Expense (FRMMA/WMPMA)
Loss Contingencies [Line Items]
Expense	236
Capital	0
Total	236
Expenses and capital expenditures, forecast	29
Transmission Safety Inspections and Repairs Expense (TO)
Loss Contingencies [Line Items]
Expense	433
Capital	0
Total	433
Vegetation Management Support Costs (FHPMA)
Loss Contingencies [Line Items]
Expense	36
Capital	0
Total	36
2017 Northern California Wildfires CEMA Expense and Capital (CEMA)
Loss Contingencies [Line Items]
Expense	82
Capital	66
Total	148
2018 Camp Fire CEMA Expense (CEMA)
Loss Contingencies [Line Items]
Expense	435
Capital	0
Total	435
2018 Camp Fire CEMA Capital for Restoration (CEMA)
Loss Contingencies [Line Items]
Expense	0
Capital	253
Total	253
2018 Camp Fire CEMA Capital for Temporary Facilities (CEMA)
Loss Contingencies [Line Items]
Expense	0
Capital	84
Total	84
Expenses and capital expenditures, forecast	$ 59

OTHER CONTINGENCIES AND COMMI_5

OTHER CONTINGENCIES AND COMMITMENTS (Locate and Mark) (Details) - USD ($) $ in Millions	Jul. 21, 2020	Jun. 30, 2020	Jan. 17, 2020	Dec. 05, 2019	Oct. 03, 2019
Loss Contingencies [Line Items]
Settlement agreement, proposed payment to California General Fund				$ 2
Unfavorable Regulatory Action
Loss Contingencies [Line Items]
Loss contingency liability		$ 44
Unfavorable Regulatory Action | Subsequent event
Loss Contingencies [Line Items]
Settlement agreement, additional fine	$ 44
Pacific Gas & Electric Co | Unfavorable Regulatory Action
Loss Contingencies [Line Items]
Settlement agreement, proposed penalty					$ 65
Settlement agreement, proposed payment to California General Fund					5
Settlement agreement, proposed payment to Shareholders' initiative fund					$ 60
Settlement agreement, compliance audits cost			$ 6
Settlement agreement, additional fine			$ 39

OTHER CONTINGENCIES AND COMMI_6

OTHER CONTINGENCIES AND COMMITMENTS (Ex Parte Communication Rules) (Details) $ in Millions	Dec. 05, 2019USD ($)
Loss Contingencies [Line Items]
Settlement agreement, proposed payment to California General Fund	$ 2
Ex Parte Communications
Loss Contingencies [Line Items]
Settlement agreement, proposed penalty	10
Settlement agreement, proposed forgone revenue collection, 2019 GT&S rate case	5
Settlement agreement, proposed forgone revenue collection, 2020 GRC cycle	1
Settlement agreement, proposed compensation payments, San Bruno	1
Settlement agreement, proposed compensation payments, San Carlos	$ 1

OTHER CONTINGENCIES AND COMMI_7

OTHER CONTINGENCIES AND COMMITMENTS (Transmission Owner Rate) (Details)	Sep. 21, 2018
Pacific Gas & Electric Co | Electric
Loss Contingencies [Line Items]
Requested revenue rate	98.85%

OTHER CONTINGENCIES AND COMMI_8

OTHER CONTINGENCIES AND COMMITMENTS (Other Matters) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Accrued legal liabilities	$ 171	$ 116

OTHER CONTINGENCIES AND COMMI_9

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

OTHER CONTINGENCIES AND COMM_10

OTHER CONTINGENCIES AND COMMITMENTS (Disallowance of Capital Expenditures) (Details) - Disallowance of Plant Costs - USD ($) $ in Millions	Jun. 23, 2016	Jun. 30, 2020	Jun. 01, 2020
Loss Contingencies [Line Items]
Gas transmission and storage capital disallowance	$ 696
Permanently disallowed capital	$ 120
Amount subject to audit		$ 576
Capital expenditures for future recovery			$ 512

OTHER CONTINGENCIES AND COMM_11

OTHER CONTINGENCIES AND COMMITMENTS (Environmental Remediation Contingencies Liability) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Disclosure Commitments And Contingencies Environmental Remediation Liability Composed [Abstract]
Topock natural gas compressor station	$ 339	$ 362
Hinkley natural gas compressor station	135	138
Former manufactured gas plant sites owned by the Utility or third parties	680	568
Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites	102	101
Fossil fuel-fired generation facilities and sites	103	106
Environmental Remediation Liability	$ 1,359	$ 1,275

OTHER CONTINGENCIES AND COMM_12

OTHER CONTINGENCIES AND COMMITMENTS (Environmental Remediation Contingencies Narrative) (Details) $ in Millions	Jun. 30, 2020USD ($)
Commitments and Contingencies Disclosure [Abstract]
Amount of environmental loss accrual expected to be recovered	$ 1,030

OTHER CONTINGENCIES AND COMM_13

OTHER CONTINGENCIES AND COMMITMENTS (Natural Gas Compressor Station Sites) (Details) $ in Millions	Jun. 30, 2020USD ($)
Topock Site
Long-term Purchase Commitment [Line Items]
Total wildfire-related claims	$ 222
Topock Site | Pacific Gas & Electric Co
Long-term Purchase Commitment [Line Items]
Remediation cost recovery percentage	90.00%
Hinkley Natural Gas Compressor Station
Long-term Purchase Commitment [Line Items]
Total wildfire-related claims	$ 137
Former Manufactured Gas Plant
Long-term Purchase Commitment [Line Items]
Total wildfire-related claims	$ 503
Remediation cost recovery percentage	90.00%
Utility Owned Generation Facilities and Third Party Disposal Sites
Long-term Purchase Commitment [Line Items]
Total wildfire-related claims	$ 66
Utility Owned Generation Facilities and Third Party Disposal Sites | Pacific Gas & Electric Co
Long-term Purchase Commitment [Line Items]
Remediation cost recovery percentage	90.00%
Fossil Fuel Fired Generation
Long-term Purchase Commitment [Line Items]
Total wildfire-related claims	$ 80

OTHER CONTINGENCIES AND COMM_14

OTHER CONTINGENCIES AND COMMITMENTS (Wildfire Insurance) (Details) - USD ($) $ in Millions	Jul. 01, 2020	Jun. 30, 2020	Jul. 31, 2020
Loss Contingencies [Line Items]
Insurance premium costs, recovery, coverage amount		$ 1,400
Insurance Coverage For Wildfire and Non-Wildfire Events | Subsequent event
Loss Contingencies [Line Items]
Costs for insurance coverage	$ 749
Insurance Coverage For Wildfire and Non-Wildfire Events | August 1, 2019 - September 2, 2020
Loss Contingencies [Line Items]
Costs for insurance coverage		212
Insurance Coverage for Wildfire Events
Loss Contingencies [Line Items]
Liability insurance coverage		430
Initial self-insured retention per occurrence		10
Insurance Coverage for Wildfire Events | Subsequent event
Loss Contingencies [Line Items]
Liability insurance coverage			$ 757.5
Initial self-insured retention per occurrence			60
Insurance Coverage for Wildfire Events | August 1, 2020 - July 31, 2021 | Subsequent event
Loss Contingencies [Line Items]
Liability insurance coverage			715
Insurance Coverage for Wildfire Events | July 1, 2020 - June 30, 2021 | Subsequent event
Loss Contingencies [Line Items]
Reinsurance			42.5
Insurance Coverage For Non-Wildfire Events
Loss Contingencies [Line Items]
Liability insurance coverage		1,000
Initial self-insured retention per occurrence		10
Insurance Coverage For Non-Wildfire Events | August 1, 2019 - July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage		520
Insurance Coverage For Non-Wildfire Events | September 3, 2019 - September 2, 2020
Loss Contingencies [Line Items]
Liability insurance coverage		$ 480
Insurance Coverage For Non-Wildfire Events | August 1, 2020 - July 31, 2021 | Subsequent event
Loss Contingencies [Line Items]
Liability insurance coverage			700
Initial self-insured retention per occurrence			$ 10

OTHER CONTINGENCIES AND COMM_15

OTHER CONTINGENCIES AND COMMITMENTS (Nuclear Insurance) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)nuclear_generating_unit
Long-term Purchase Commitment [Line Items]
Number of nuclear generating units (nuclear generating unit) | nuclear_generating_unit	2
Nuclear Electric Insurance Limited
Long-term Purchase Commitment [Line Items]
Amount of property damage and business interruption coverage provided by NEIL for Diablo Canyon	$ 43
European Mutual Association for Nuclear Insurance
Long-term Purchase Commitment [Line Items]
Amount of property damage coverage provided by NEIL	$ 4

OTHER CONTINGENCIES AND COMM_16

OTHER CONTINGENCIES AND COMMITMENTS (Tax Matters) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)
Pacific Gas & Electric Co
Disaggregation of Revenue [Line Items]
Unrecognized tax benefits, decrease resulting from settlements with taxing authorities	$ 30

OTHER CONTINGENCIES AND COMM_17

OTHER CONTINGENCIES AND COMMITMENTS (Purchase Commitments) (Details) $ in Billions	Dec. 31, 2019USD ($)
Commitments and Contingencies Disclosure [Abstract]
Recorded unconditional purchase obligation	$ 38

OTHER CONTINGENCIES AND COMM_18

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

Subsequent Events (Details)

Subsequent Events (Details) - Noteholder RSA Breach Claim - Subsequent event $ in Millions	Jul. 27, 2020USD ($)
Subsequent Event [Line Items]
Administrative claims	$ 250
Transfer of backstop commitments	$ 2,000