PG&E (PCG) 10-Q 1 May 20 2020 Q1 Quarterly report Financial data

Cover Page

Cover Page - shares	3 Months Ended
	Mar. 31, 2020	Apr. 27, 2020
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 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)		529,785,896
Amendment Flag	false
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1
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
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
	Mar. 31, 2020	Mar. 31, 2019
Operating Revenues
Total operating revenues	$ 4,306	$ 4,011
Operating Expenses
Operating and maintenance	1,967	2,087
Depreciation, amortization, and decommissioning	855	797
Total operating expenses	3,651	3,822
Operating Income	655	189
Interest income	16	22
Interest expense	(254)	(103)
Other income, net	97	71
Reorganization items, net	(176)	(127)
Income Before Income Taxes	338	52
Income tax benefit	(36)	(84)
Net Income	374	136
Preferred stock dividend requirement of subsidiary	3	0
Income Available for Common Shareholders	$ 371	$ 136
Weighted Average Common Shares Outstanding, Basic (in shares)	529	526
Weighted Average Common Shares Outstanding, Diluted (in shares)	648	527
Net Income Per Common Share, Basic (in dollars per share)	$ 0.70	$ 0.25
Net Income Per Common Share, Diluted (in dollars per share)	$ 0.57	$ 0.25
Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	$ 4,306	$ 4,011
Operating Expenses
Operating and maintenance	1,965	2,104
Depreciation, amortization, and decommissioning	855	797
Total operating expenses	3,649	3,839
Operating Income	657	172
Interest income	16	21
Interest expense	(252)	(101)
Other income, net	93	66
Reorganization items, net	(93)	(111)
Income Before Income Taxes	421	47
Income tax benefit	(30)	(86)
Net Income	451	133
Preferred stock dividend requirement of subsidiary	3	0
Income Available for Common Shareholders	448	133
Electric
Operating Revenues
Total operating revenues	3,040	2,792
Operating Expenses
Cost of goods	545	599
Electric | Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	3,040	2,792
Operating Expenses
Cost of goods	545	599
Natural gas
Operating Revenues
Total operating revenues	1,266	1,219
Operating Expenses
Cost of goods	284	339
Natural gas | Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	1,266	1,219
Operating Expenses
Cost of goods	$ 284	$ 339

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Net Income	$ 374	$ 136
Other Comprehensive Income
Pension and other post-retirement benefit plans obligations (net of taxes of $0 and $0, respectively)	0	0
Total other comprehensive income	0	0
Comprehensive Income	374	136
Preferred stock dividend requirement of subsidiary	3	0
Comprehensive Income Available for Common Shareholders	371	136
Pacific Gas & Electric Co
Net Income	451	133
Other Comprehensive Income
Pension and other post-retirement benefit plans obligations (net of taxes of $0 and $0, respectively)	0	0
Total other comprehensive income	0	0
Comprehensive Income	$ 451	$ 133

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Pension and other postretirement benefit plans obligations tax	$ 0	$ 0
Pacific Gas & Electric Co
Pension and other postretirement benefit plans obligations tax	$ 0	$ 0

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Current Assets
Cash and cash equivalents	$ 1,960	$ 1,570
Accounts receivable:
Customers (net of allowance for doubtful accounts of $46 and $43 at respective dates)	1,319	1,287
Accrued unbilled revenue	946	969
Regulatory balancing accounts	2,102	2,114
Other	2,613	2,617
Regulatory assets	373	315
Inventories:
Gas stored underground and fuel oil	77	97
Materials and supplies	567	550
Other	601	646
Total current assets	10,558	10,165
Property, Plant, and Equipment
Electric	63,750	62,707
Gas	23,045	22,688
Construction work in progress	2,670	2,675
Other	20	20
Total property, plant, and equipment	89,485	88,090
Accumulated depreciation	(26,987)	(26,455)
Net property, plant, and equipment	62,498	61,635
Other Noncurrent Assets
Regulatory assets	6,604	6,066
Nuclear decommissioning trusts	2,911	3,173
Operating lease right of use asset	2,209	2,286
Income taxes receivable	67	67
Other	1,841	1,804
Total other noncurrent assets	13,632	13,396
TOTAL ASSETS	86,688	85,196
Current Liabilities
Debtor-in-possession financing, classified as current	2,000	1,500
Accounts payable:
Trade creditors	1,851	1,954
Regulatory balancing accounts	1,845	1,797
Other	699	566
Operating lease liabilities	554	556
Interest payable	4	4
Other	1,300	1,254
Total current liabilities	8,253	7,631
Noncurrent Liabilities
Regulatory liabilities	9,251	9,270
Pension and other post-retirement benefits	1,855	1,884
Asset retirement obligations	5,902	5,854
Deferred income taxes	505	320
Operating lease liabilities	1,655	1,730
Other	2,757	2,573
Total noncurrent liabilities	21,925	21,631
Liabilities Subject to Compromise	50,751	50,546
Shareholders’ Equity
Common stock	13,035	13,038
Reinvested earnings	(7,518)	(7,892)
Accumulated other comprehensive loss	(10)	(10)
Total shareholders’ equity	5,507	5,136
Noncontrolling Interest - Preferred Stock of Subsidiary	252	252
Total equity	5,759	5,388
TOTAL LIABILITIES AND EQUITY	86,688	85,196
Pacific Gas & Electric Co
Current Assets
Cash and cash equivalents	1,555	1,122
Accounts receivable:
Customers (net of allowance for doubtful accounts of $46 and $43 at respective dates)	1,319	1,287
Accrued unbilled revenue	946	969
Regulatory balancing accounts	2,102	2,114
Other	2,651	2,647
Regulatory assets	373	315
Inventories:
Gas stored underground and fuel oil	77	97
Materials and supplies	567	550
Other	588	635
Total current assets	10,178	9,736
Property, Plant, and Equipment
Electric	63,750	62,707
Gas	23,045	22,688
Construction work in progress	2,670	2,675
Other	18	18
Total property, plant, and equipment	89,483	88,088
Accumulated depreciation	(26,985)	(26,453)
Net property, plant, and equipment	62,498	61,635
Other Noncurrent Assets
Regulatory assets	6,604	6,066
Nuclear decommissioning trusts	2,911	3,173
Operating lease right of use asset	2,202	2,279
Income taxes receivable	66	66
Other	1,692	1,659
Total other noncurrent assets	13,475	13,243
TOTAL ASSETS	86,151	84,614
Current Liabilities
Debtor-in-possession financing, classified as current	2,000	1,500
Accounts payable:
Trade creditors	1,819	1,949
Regulatory balancing accounts	1,845	1,797
Other	786	675
Operating lease liabilities	551	553
Interest payable	4	4
Other	1,310	1,263
Total current liabilities	8,315	7,741
Noncurrent Liabilities
Regulatory liabilities	9,251	9,270
Pension and other post-retirement benefits	1,855	1,884
Asset retirement obligations	5,902	5,854
Deferred income taxes	633	442
Operating lease liabilities	1,651	1,726
Other	2,817	2,626
Total noncurrent liabilities	22,109	21,802
Liabilities Subject to Compromise	49,941	49,736
Shareholders’ Equity
Preferred stock	258	258
Common stock	1,322	1,322
Additional paid-in capital	8,550	8,550
Reinvested earnings	(4,345)	(4,796)
Accumulated other comprehensive loss	1	1
Total shareholders’ equity	5,786	5,335
TOTAL LIABILITIES AND EQUITY	$ 86,151	$ 84,614

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Allowance for doubtful accounts	$ 46	$ 43
Common stock, par value (in dollars per share)	$ 0	$ 0
Common stock, shares authorized (in shares)	800,000,000	800,000,000
Common stock, shares outstanding (in shares)	529,785,896	529,236,741
Pacific Gas & Electric Co
Allowance for doubtful accounts	$ 46	$ 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	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Cash Flows from Operating Activities
Net Income	$ 374	$ 136
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	855	797
Allowance for equity funds used during construction	(10)	(25)
Deferred income taxes and tax credits, net	197	4
Reorganization Items	50	19
Other	35	16
Effect of changes in operating assets and liabilities:
Accounts receivable	(22)	(31)
Wildfire-related insurance receivable	0	25
Inventories	3	18
Accounts payable	245	(180)
Wildfire-related claims	0	(14)
Income taxes receivable/payable	0	23
Other current assets and liabilities	(123)	150
Regulatory assets, liabilities, and balancing accounts, net	(310)	343
Liabilities subject to compromise	208	833
Other noncurrent assets and liabilities	103	130
Net cash provided by operating activities	1,605	2,244
Cash Flows from Investing Activities
Capital expenditures	(1,641)	(1,224)
Proceeds from sales and maturities of nuclear decommissioning trust investments	533	346
Purchases of nuclear decommissioning trust investments	(552)	(372)
Other	5	3
Net cash used in investing activities	(1,655)	(1,247)
Cash Flows from Financing Activities
Proceeds from debtor-in-possession credit facility	500	350
Debtor-in-possession credit facility debt issuance costs	(3)	(111)
Bridge facility financing fees	(66)	0
Common stock issued	0	85
Other	9	(24)
Net cash provided by financing activities	440	300
Net change in cash, cash equivalents, and restricted cash	390	1,297
Cash, cash equivalents, and restricted cash at January 1	1,577	1,675
Cash, cash equivalents, and restricted cash at March 31	1,967	2,972
Less: Restricted cash and restricted cash equivalents included in other current assets	(7)	(8)
Cash and cash equivalents	1,960	2,964
Cash paid for:
Interest, net of amounts capitalized	0	(10)
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	326	242
Operating lease liabilities arising from obtaining right-of-use assets	13	2,816
Pacific Gas & Electric Co
Cash Flows from Operating Activities
Net Income	451	133
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	855	797
Allowance for equity funds used during construction	(10)	(25)
Deferred income taxes and tax credits, net	202	2
Reorganization Items	(11)	20
Other	40	12
Effect of changes in operating assets and liabilities:
Accounts receivable	(30)	(51)
Wildfire-related insurance receivable	0	25
Inventories	3	18
Accounts payable	221	(132)
Wildfire-related claims	0	(14)
Income taxes receivable/payable	0	5
Other current assets and liabilities	(121)	171
Regulatory assets, liabilities, and balancing accounts, net	(310)	343
Liabilities subject to compromise	208	833
Other noncurrent assets and liabilities	114	137
Net cash provided by operating activities	1,612	2,274
Cash Flows from Investing Activities
Capital expenditures	(1,641)	(1,224)
Proceeds from sales and maturities of nuclear decommissioning trust investments	533	346
Purchases of nuclear decommissioning trust investments	(552)	(372)
Other	5	3
Net cash used in investing activities	(1,655)	(1,247)
Cash Flows from Financing Activities
Proceeds from debtor-in-possession credit facility	500	350
Debtor-in-possession credit facility debt issuance costs	(3)	(95)
Bridge facility financing fees	(30)	0
Other	9	(24)
Net cash provided by financing activities	476	231
Net change in cash, cash equivalents, and restricted cash	433	1,258
Cash, cash equivalents, and restricted cash at January 1	1,129	1,302
Cash, cash equivalents, and restricted cash at March 31	1,562	2,560
Less: Restricted cash and restricted cash equivalents included in other current assets	(7)	(8)
Cash and cash equivalents	1,555	2,552
Cash paid for:
Interest, net of amounts capitalized	0	(8)
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	326	242
Operating lease liabilities arising from obtaining right-of-use assets	$ 13	$ 2,807

CONDENSED CONSOLIDATED STATEM_5

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	136		136		136		$ 133				133		133
Other comprehensive income (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, 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	374		374		374		$ 451				451		451
Other comprehensive income (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	529,785,896					264,374,809
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

ORGANIZATION AND BASIS OF PRESE

ORGANIZATION AND BASIS OF PRESENTATION	3 Months Ended
	Mar. 31, 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 wildfire-related liabilities, regulatory assets and liabilities, legal and regulatory contingencies, insurance receivables, environmental remediation liabilities, AROs, pension and other post-retirement benefit plan obligations, and the valuation of LSTC. 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 Filing 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. However, as a result of the challenges that are further described below, such realization of assets and satisfaction of liabilities are subject to uncertainty. 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. See Note 10 below. Uncertainty regarding these matters raises substantial doubt about PG&E Corporation’s and the Utility’s abilities to continue as going concerns. PG&E Corporation and the Utility have determined that commencing reorganization cases under Chapter 11 was necessary to restore PG&E Corporation’s and the Utility’s financial stability to fund ongoing operations and provide safe service to customers. However, there can be no assurance that such proceedings will restore PG&E Corporation’s and the Utility’s financial stability. On the Petition Date, PG&E Corporation and the Utility filed voluntary petitions for relief under Chapter 11 in the Bankruptcy Court. The Condensed Consolidated Financial Statements do not include any adjustments that might be necessary should PG&E Corporation and the Utility be unable to continue as going concerns.

BANKRUPTCY FILING

BANKRUPTCY FILING	3 Months Ended
	Mar. 31, 2020
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. PG&E Corporation and the Utility continue 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, are subject to an automatic stay. Absent an order of the Bankruptcy Court providing otherwise, substantially all pre-petition liabilities will be resolved under a Chapter 11 plan of reorganization to be voted upon by impaired creditors and interest holders, and approved by the Bankruptcy Court. However, under the Bankruptcy Code, regulatory or criminal proceedings generally are not subject to an automatic stay, and these proceedings have been continuing during the pendency of the Chapter 11 Cases. Under the priority scheme established by the Bankruptcy Code, certain post-petition and secured or “priority” pre-petition liabilities need to be satisfied before general unsecured creditors and holders of PG&E Corporation’s and the Utility’s equity are entitled to receive any distribution. No assurance can be given as to what values, if any, will be ascribed in the Chapter 11 Cases to the claims and interests of each of these constituencies. Additionally, no assurance can be given as to whether, when or in what form unsecured creditors and holders of PG&E Corporation’s or the Utility’s equity may receive a distribution on such claims or interests. Under the Bankruptcy Code, PG&E Corporation and the Utility may assume, assume and assign, or reject certain executory contracts and unexpired leases, including, without limitation, leases of real property and equipment, subject to the approval of the Bankruptcy Court and to certain other conditions. Any description of an executory contract or unexpired lease in this quarterly report on Form 10-Q, or in the 2019 Form 10-K, including, where applicable, the express termination rights thereunder or a quantification of their obligations, must be read in conjunction with, and is qualified by, any overriding rejection rights PG&E Corporation and the Utility have under the Bankruptcy Code. Significant Bankruptcy Court Actions First Day Motions On January 31, 2019, the Bankruptcy Court approved, on an interim basis, certain motions (the “First Day Motions”) authorizing, but not directing, PG&E Corporation and the Utility to, among other things, (a) secure $5.5 billion of debtor-in-possession financing; (b) continue to use PG&E Corporation’s and the Utility’s cash management system; and (c) pay certain pre-petition claims relating to (i) certain safety, reliability, outage, and nuclear facility suppliers; (ii) shippers, warehousemen, and other lien claimants; (iii) taxes; (iv) employee wages, salaries, and other compensation and benefits; and (v) customer programs, including public purpose programs. The First Day Motions were subsequently approved by the Bankruptcy Court on a final basis at hearings on February 27, 2019, March 12, 2019, March 13, 2019, and March 27, 2019. Bar Date On July 1, 2019, the Bankruptcy Court entered an order approving a deadline of October 21, 2019, at 5:00 p.m. (Pacific Time) (the “Bar Date”) for filing claims against PG&E Corporation and the Utility relating to the period prior to the Petition Date. The Bar Date is subject to certain exceptions, including for claims arising under section 503(b)(9) of the Bankruptcy Code, the bar date for which occurred on April 22, 2019. The Bankruptcy Court also approved PG&E Corporation’s and the Utility’s plan to provide notice of the Bar Date to parties in interest, including potential wildfire-related claimants and other potential creditors. On November 11, 2019, the Bankruptcy Court entered an order approving a stipulation between PG&E Corporation and the Utility and the TCC to extend the Bar Date for unfiled, non-governmental fire claimants to December 31, 2019, at 5:00 p.m. (Pacific Time). By order dated February 27, 2020, the Court extended the Bar Date through and including April 16, 2020, for certain persons or entities that purchased or acquired the PG&E Corporation’s and the Utility’s publicly traded debt or equity securities and who may have claims under the securities laws against the Debtors for rescission or damages. Other Significant Actions Related to the Chapter 11 Cases Other significant actions and developments related to the Chapter 11 Cases, including the Tubbs Lift Stay Decision, the Tubbs Trial and the Estimation Proceeding are described in Note 10 (including under the headings “Proceeding in San Francisco County Superior Court for Certain Tubbs Fire-Related Claims” and “Wildfire Claims Estimation Proceeding in the U.S. District Court for the Northern District of California”). Plan of Reorganization, RSA, Equity Backstop Commitments and Debt Commitment Letters On September 9, 2019, PG&E Corporation and the Utility filed with the Bankruptcy Court their Joint Chapter 11 Plan of Reorganization for the resolution of the outstanding pre-petition claims against and interests in PG&E Corporation and the Utility, which was thereafter amended on September 23, 2019 and November 4, 2019. On December 12, 2019, 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 the Debtors’ and Shareholder Proponents’ Joint Chapter 11 Plan of Reorganization dated December 19, 2019 with the Bankruptcy Court (as thereafter amended on January 31, 2020, March 9, 2020 and March 16, 2020, and as may be further amended, modified or supplemented from time to time, the “Plan”). 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”). On September 22, 2019, PG&E Corporation and the Utility and the Consenting Subrogation Creditors entered into an amended and restated Restructuring Support Agreement, which was subsequently amended on November 1, 2019, (as amended, the “Subrogation RSA”). The Subrogation RSA provides for an aggregate amount of $11.0 billion (the “Allowed Subrogation Claim Amount”) to be paid by PG&E Corporation and the Utility pursuant to the Plan in order to settle all insurance subrogation claims (the “Subrogation Claims”) relating to the 2017 Northern California wildfires and the 2018 Camp fire (the “Subrogation Claims Settlement”), upon the terms and conditions set forth in the Subrogation RSA. Under the Subrogation RSA, PG&E Corporation and the Utility also have 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. See “Restructuring Support Agreement with Holders of Subrogation Claims” in Note 10 for further information on the Subrogation RSA. On September 24, 2019, PG&E Corporation and the Utility filed a motion with the Bankruptcy Court seeking authority to enter into, and perform under, the Subrogation RSA and approval of the Subrogation Claims Settlement. Hearings on PG&E Corporation’s and the Utility’s motion to approve the Subrogation RSA were held on October 23, 2019, December 4, 2019 and December 17, 2019. 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 Fire Victim Claims (as defined below) that are signatories to the TCC RSA (each a “Consenting Fire Claimant Professional”), and the Shareholder Proponents. The TCC RSA provides for, among other things, an aggregate of $13.5 billion in value to be provided by PG&E Corporation and the Utility pursuant to the Plan in order to settle and discharge all 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 the Public Entity Wildfire Claims) (the “Fire Victim Claims”), upon the terms and conditions set forth in the TCC RSA and the Plan. On December 9, 2019, PG&E Corporation and the Utility filed a motion with the Bankruptcy Court seeking authority to enter into, and perform under, the TCC RSA. A hearing on PG&E Corporation’s and the Utility’s motion to approve the TCC RSA was held on December 17, 2019. 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. Plan of Reorganization The Plan proposes the following: • compensation of wildfire victims and certain public entities from a trust funded for their benefit in an aggregate value of approximately $13.5 billion (as further described under the heading “Restructuring Support Agreement with the TCC” in Note 10); • compensation of insurance subrogation claimants from a trust funded for their benefit in the amount of $11.0 billion in cash (as further described under the heading “Restructuring Support Agreement with Holders of Subrogation Claims” in Note 10); • payment of $1.0 billion in cash in full settlement of the claims of the settling public entities relating to the wildfires (as further described under the heading “Plan Support Agreements with Public Entities” in Note 10); • entitlement for the holders of claims related to the 2016 Ghost Ship fire to pursue their claims after the Effective Date, with any recovery being limited to amounts available under PG&E Corporation’s and the Utility’s insurance policies; • refinancing of Utility Short-Term Notes, Utility Long-Term Notes and Utility Funded Debt (except Pollution Control Bonds Series 2008F and 2010E, which will be repaid in cash) with the issuance of new notes, reinstatement of Utility Reinstated Notes and reimbursement of 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 $99 million (as further described under the heading “Restructuring Support Agreement with the Ad Hoc Noteholder Committee”); • payment in full of all pre-petition funded debt obligations of PG&E Corporation, all pre-petition trade claims and all pre-petition employee-related unsecured claims; • assumption of all power purchase agreements and community choice aggregation servicing agreements; • assumption of all pension obligations, other employee obligations, and collective bargaining agreements with labor; • future participation in the state wildfire fund established by AB 1054; and • satisfaction of the requirements of AB 1054. The Plan proposes the following key financing sources: • one or more equity offerings of up to $9.0 billion, in accordance with the Backstop Commitment Letters, although the Backstop Commitment Letters (as described below) permit PG&E Corporation to draw up to $12.0 billion; • the issuance of $6.75 billion of new equity to the Fire Victim Trust; • 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; • the issuance of $23.775 billion of new Utility debt, consisting of (i) $6.2 billion of New Utility Long-Term Notes 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 Notes to be issued to holders of certain pre-petition senior notes of the Utility pursuant to the Plan, (iii) $3.9 billion of Utility Funded Debt Exchange Notes 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); • approximately $2.2 billion in proceeds of PG&E Corporation’s and the Utility’s liability insurance proceeds for wildfire events; and • cash available to PG&E Corporation or the Utility immediately prior to the Effective Date. On October 4, 2019, the CPUC issued an OII to consider the ratemaking and other implications of the Plan. The Plan has not been approved and is subject to regulatory review by the CPUC and FERC, as and to the extent required by law, including as potentially causing a change in control under Section 203 of the Federal Power Act. The Plan may be further amended, modified, or supplemented as necessary or desired by PG&E Corporation and the Utility or as required by the Bankruptcy Court or the CPUC. PG&E Corporation and the Utility expect that the CPUC and FERC will issue decisions in advance of the June 30, 2020 deadline for Plan confirmation. On March 20, 2020, the Debtors filed a motion with the Bankruptcy Court 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”). As further described in the motion, the Case Resolution Contingency Process contemplates a process for the sale of PG&E Corporation or the Utility in the event that the Plan is not confirmed or fails to become effective in accordance with certain required dates. In addition, the motion sets forth certain other commitments by the Debtors 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. Also on March 20, 2020, the California Governor filed a responsive pleading in the Bankruptcy Court stating that, assuming the Bankruptcy Court grants the Motion and the California Public Utilities Commission (“CPUC”) approves the Plan with the governance, financial and operational provisions submitted to the CPUC by the Utility or otherwise agreed by the Utility, with any modifications the CPUC believes appropriate or necessary, the Plan “will, in the Governor’s judgment, be compliant with AB 1054.” The Governor’s pleading also states that “a rate neutral securitization pursuant to Senate Bill 901...would, in [the Governor’s] judgment, be in the public interest...” Following a hearing held on April 7, 2020, the Bankruptcy Court indicated that it would approve the Debtors’ motion and the Case Resolution Contingency Process, subject to certain reservations of rights, and directed the Debtors to submit an order to that effect. The Bankruptcy Court entered the order approving the motion on April 9, 2020. Disclosure Statement On February 7, 2020, pursuant to section 1125 of the Bankruptcy Code, PG&E Corporation and the Utility filed a proposed disclosure statement (as updated, the “Proposed Disclosure Statement”), with all schedules and exhibits thereto, for the Plan. On February 18, 2020, PG&E Corporation and the Utility filed certain projections with the Bankruptcy Court as an exhibit to the Proposed Disclosure Statement, and on March 9, 2020, PG&E Corporation and the Utility filed an updated Proposed Disclosure Statement with revised financial projections as an exhibit with the Bankruptcy Court. PG&E Corporation and the Utility filed on February 18, 2020, a motion requesting that the Court (i) establish Plan solicitation and voting procedures, and (ii) approve the forms of Ballots, Solicitation Packages, and related notices to be sent to the various creditors and interest holders in connection with confirmation of the Plan (the “Solicitation Procedures Motion”). By order dated March 17, 2020, the Bankruptcy Court approved the Proposed Disclosure Statement and the Solicitation Procedures Motion. Pursuant to the Solicitation Procedures Motion, PG&E Corporation and the Utility mailed the Ballots, Solicitation Packages and related notices by March 31, 2020, and votes are due by May 15, 2020. A hearing to consider confirmation of the Plan is scheduled for May 27, 2020. 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” below 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, each as defined below, and (ii) the reinstatement of the Utility Reinstated Senior Notes, as defined below (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 have 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 $99 million upon the terms and conditions set forth in the Noteholder RSA. The following holders of Utility Senior Notes Claims are party to the Noteholder RSA as “Consenting Noteholders” as of the date hereof: Apollo Global Management LLC, Elliott Management Corporation, Oaktree Capital Management L.P., Farallon Capital Management LLC, Capital Group, Värde Partners Inc., Davidson Kempner Capital Management LP, Canyon Capital Advisors LLC, Third Point LLC, Pacific Investment Management Company LLC, Citadel Advisors LLC and Sculptor Capital Investments, LLC. Any holder of Utility Senior Note Claims or Utility Funded Debt can become a party to the Noteholder RSA by executing the joinder attached to the Noteholder RSA. The Noteholder RSA provides for the following treatment of Utility Senior Note Claims and Utility Funded Debt which treatment has been incorporated into the Plan: • Utility Short-Term Senior Notes: Currently outstanding Utility notes maturing through 2022 in an aggregate principal amount of $1.75 billion (the “Utility Short-Term Senior Notes”) will receive new Utility secured notes in the following aggregate principal amounts: $875 million of new Utility 3.45% secured notes due 2025 and $875 million of new Utility 3.75% secured notes due 2028 (together, the “New Utility Short-Term Notes”). The New Utility Short-Term Notes will 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 will receive 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”), will receive new Utility secured notes in the following aggregate principal amounts: $3.1 billion of new Utility 4.55% secured notes due 2030 and $3.1 billion of new Utility 4.95% secured notes due 2050 (together, the “New Utility Long-Term Notes”). The New Utility Long-Term Notes will 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 will receive 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”) will be 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. • Utility Funded Debt: Holders of the Utility’s pre-petition credit facilities and Pollution Control bonds (collectively, the “Utility Funded Debt”) will receive new Utility secured notes in the following aggregate principal amounts: $1.949 billion in new Utility 3.15% senior secured notes due 2025, and $1.949 billion in new Utility 4.50% senior secured notes due 2040 (the “New Utility Funded Debt Exchange Notes”). The New Utility Funded Debt Exchange Notes will 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 Funded Debt will receive 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. On February 5, 2020, the Bankruptcy Court entered an order approving the Noteholder RSA. For more information regarding the terms of the Noteholder RSA, see Note 2 of the Notes to the Consolidated Financial Statements in Item 8 of the 2019 Form 10-K. Equity Backstop Commitments As of March 6, 2020, PG&E Corporation has entered into Chapter 11 Plan Backstop Commitment Letters (collectively, 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”). The price at which any such new shares would be issued to the Backstop Parties would be equal to (a) 10 (subject to adjustment as provided in the Backstop Commitment Letters), times (b) PG&E Corporation’s consolidated Normalized Estimated Net Income (as defined in the Backstop Commitment Letters) for the estimated year 2021, divided by (c) the number of fully diluted shares of PG&E Corporation that will be outstanding on the effective date of the Plan (the “Effective Date”) (assuming that all equity is raised by funding the Backstop Commitments). The Backstop Commitment Letters provide that, under certain circumstances, PG&E Corporation and the Utility will be permitted to issue new shares of common stock of PG&E Corporation for up to $12.0 billion of proceeds to finance the transactions contemplated by the Plan through one or more equity offerings that, under certain circumstances, must include a rights offering (the “Rights Offering”). The structure, terms and conditions of any such equity offering (including a Rights Offering) are expected to be determined by PG&E Corporation and the Utility at a later time in the Chapter 11 process, subject to the terms and conditions of the Backstop Commitment Letters. This may include terms and conditions that are designed to preserve the ability of PG&E Corporation or the Utility to utilize their net operating loss carryforwards. There can be no assurance that any such equity offering would be successful. In the event that such equity offerings (together with additional permitted capital sources) do not raise at least $12.0 billion of proceeds in the aggregate or if PG&E Corporation and the Utility do not otherwise consummate such offerings, then PG&E Corporation and the Utility may draw on the Backstop Commitments for equity funding to finance the transactions contemplated by the Plan, subject to the satisfaction or waiver by the Backstop Parties of the conditions set forth therein. Although the Backstop Commitment Letters permit PG&E Corporation to draw up to $12.0 billion in equity under specified circumstances, the Plan contemplates an equity raise of only $9.0 billion, the maximum available under these circumstances, which equity will be raised in accordance with the terms of the Backstop Commitment Letters. Under the Backstop Commitment Letters, PG&E Corporation agrees that if the Backstop Commitments are drawn, and PG&E Corporation does not expect to conduct a third-party transaction based upon or related to the utilization or monetization of any net operating losses or tax deductions resulting from the payment of pre-petition wildfire-related claims (a “Tax Benefits Monetization Transaction”) on the Effective Date, no later than five business days prior to the Effective Date, PG&E Corporation and the Utility must form a trust which would provide for periodic distributions of cash to the Backstop Parties in amounts equal to (i) all tax benefits arising from the payment of wildfire-related claims in excess of (ii) the first $1.35 billion of tax benefits, starting with fiscal year 2020. PG&E Corporation intends to explore a Tax Benefits Monetization Transaction. If PG&E Corporation and the Utility implement the capital structure outlined in the Debtors’ Plan of Reorganization OII Prepared Testimony filed with the California Public Utilities Commission on January 31, 2020, such capital structure will be deemed to include a $6.0 billion “Tax Benefits Monetization Transaction” for the purposes of the Backstop Commitment Letter. The Backstop Parties’ funding obligations under the Backstop Commitment Letters are subject to numerous conditions, including, among others, that (a) the Backstop Commitment Letters have been approved by the Bankruptcy Court, (b) the conditions precedent to the Effective Date set forth in the Plan have been satisfied or waived in accordance with the Plan, (c) the Bankruptcy Court has entered an order confirming the Plan and approving the transactions contemplated thereunder, which shall confirm the Plan with such amendments, modifications, changes and consents as are approved by holders of a majority of the aggregate Backstop Commitments (the “Confirmation Order”), (d) PG&E Corporation’s and the Utility’s weighted average earning rate base for 2021 is no less than 95% of $48 billion, and (e) there has been no event, occurrence or other circumstance that would have or would reasonably be expected to have a material adverse effect on the business of PG&E Corporation and the Utility or their ability to consummate the transactions contemplated by the Backstop Commitment Letters and the Plan. In addition, the Backstop Parties have certain termination rights under the Backstop Commitment Letters, including, among others, if: • the Plan (including as may be amended, modified or otherwise changed) does not include Abrams and Knighthead as plan proponents and is not in a form acceptable to each of Abrams and Knighthead, • PG&E Corporation’s and the Utility’s aggregate liability with respect to pre-petition wildfire-related claims exceeds $25.5 billion, • the Plan is amended without the consent of the holders of a majority of the aggregate Backstop Commitments, • the Confirmation Order has not been entered by the Bankruptcy Court by June 30, 2020, • the Effective Date has not occurred within 60 days of entry of the Confirmation Order, • a material adverse effect (as described above) occurs, • the CPUC fails to issue all necessary approvals, authorizations and final orders to implement the Plan prior to June 30, 2020, including approvals related to the Utility’s capital structure and authorized rate of return and the resolution of the CPUC’s claims against the Utility for fines or penalties, all of which must be satisfactory to the holders of a majority of the aggregate Backstop Commitments, • the amount of asserted administrative expense claims or the amount of administrative expense claims PG&E Corporation and the Utility have reserved for and/or paid in the aggregate exceeds $250 million, net of insurance, in each case excluding administrative expense claims that are ordinary course, professional fee claims, claims that are disallowed in the Chapter 11 Cases and the portion of an administrative expense claim that is covered by insurance, • one or more wildfires occur in the Utility’s service area on or after January 1, 2020 that damage or destroy at least 500 dwellings or commercial structures in the aggregate at a time when the portion of the Utility’s system at the location of such wildfire was not successfully de-energized, • as of the Effective Date, the Utility has not elected and received Bankruptcy Court approval, or satisfied the other required conditions, to participate in the statewide wildfire fund established by AB 1054, • at any time the Bankruptcy Court determines that PG&E Corporation and the Utility are insolvent, • PG&E Corporation and the Utility enter into any Tax Benefit Monetization Transaction and the net cash proceeds thereof are less than $3.0 billion, excluding the $1.35 billion of tax benefits to be utilized in the Plan, and • the Plan or any supplements to or other documents in connection with the Plan has been amended, modified or changed, without the consent of the holders of at least 66 2/3% of the aggregate Backstop Commitments, to include a process for transferring the license and operating assets of the Utility to the State of California or a third party (a “Transfer”) or PG&E Corporation and the Utility effect a Transfer other than pursuant to the Plan. There can be no assurance that the conditions precedent set forth in the Backstop Commitment Letters will be satisfied or waived, nor that events or circumstances will not occur that give rise to termination rights of the Backstop Parties. The commitment premium for the Backstop Commitments is paid in shares of PG&E Corporation’s common stock (with each Backstop Party receiving its pro rata share of 119.0 million shares of the Corporation’s common stock based on the proportion of the amount of such Backstop Party’s Backstop Commitment to $12 billion). This aggregate 119 million share amount will be adjusted through the issuance of additional shares in the event that the aggregate value of the 119 million shares paid as the Backstop Commitment premium is less than $764 million based on the market price of the Corporation’s common stock following the Effective Date, subject to a cap of 19,909,091 additional shares in total. Such commitment premium was earned in full upon Bankruptcy Court approval of the Backstop Commitment Letters, subject to clawback under certain circumstances set forth in the Backstop Commitment Letters. In the event that a plan of

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	3 Months Ended
	Mar. 31, 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 March 31, 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 March 31, 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 months ended March 31, 2020 and 2019 were as follows: Pension Benefits Other Benefits Three Months Ended March 31, (in millions) 2020 2019 2020 2019 Service cost for benefits earned (1) $ 132 $ 111 $ 15 $ 14 Interest cost 178 189 16 19 Expected return on plan assets (261) (227) (34) (31) Amortization of prior service cost (1) (1) 3 4 Amortization of net actuarial loss 1 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. 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. On February 27, 2019, PG&E Corporation and the Utility received final approval from the Bankruptcy Court to maintain existing pension and other benefit plans, other than the non-qualified pension plan, during the pendency of the Chapter 11 Cases. 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 March 31, 2020 Beginning balance $ (22) $ 17 $ (5) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $0 and $1, respectively) (1) 2 1 Amortization of net actuarial loss (net of taxes of $0 and $2, respectively) 1 (3) (2) Regulatory account transfer (net of taxes of $0 and $1, respectively) — 1 1 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 March 31, 2019 Beginning balance $ (21) $ 17 $ (4) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $0 and $1, respectively) (1) 3 2 Amortization of net actuarial loss (net of taxes of $0, and $0, respectively) 1 (1) — Regulatory account transfer (net of taxes of $0 and $1, respectively) — (2) (2) 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 its 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 March 31, (in millions) 2020 2019 Electric Revenue from contracts with customers Residential $ 1,242 $ 1,288 Commercial 1,007 953 Industrial 341 293 Agricultural 123 86 Public street and highway lighting 17 17 Other (1) (66) (309) Total revenue from contracts with customers - electric 2,664 2,328 Regulatory balancing accounts (2) 376 464 Total electric operating revenue $ 3,040 $ 2,792 Natural gas Revenue from contracts with customers Residential $ 1,066 $ 1,171 Commercial 234 240 Transportation service only 348 382 Other (1) (22) (75) Total revenue from contracts with customers - gas 1,626 1,718 Regulatory balancing accounts (2) (360) (499) Total natural gas operating revenue 1,266 1,219 Total operating revenues $ 4,306 $ 4,011 (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. 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. 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. The ASU will be effective for PG&E Corporation and the Utility in 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. 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. The ASU will be effective for PG&E Corporation and the Utility before December 31, 2022. PG&E Corporation and the Utility are currently evaluating the impact the guidance will have on their Condensed Consolidated Financial Statements and related disclosures.

REGULATORY ASSETS, LIABILITIES,

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	3 Months Ended
	Mar. 31, 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) March 31, 2020 December 31, 2019 Pension benefits (1) $ 1,790 $ 1,823 Environmental compliance costs 1,053 1,062 Utility retained generation (2) 216 228 Price risk management 138 124 Unamortized loss, net of gain, on reacquired debt 59 63 Catastrophic event memorandum account (3) 684 656 Wildfire expense memorandum account (4) 443 423 Fire hazard prevention memorandum account (5) 260 259 Fire risk mitigation memorandum account (6) 96 95 Wildfire mitigation plan memorandum account (7) 840 558 Deferred income taxes (8) 468 252 Other 557 523 Total long-term regulatory assets $ 6,604 $ 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 specific incremental wildfire-related liability costs the CPUC approved for tracking in June 2018. 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 March 31, 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. Regulatory Liabilities Long-term regulatory liabilities are comprised of the following: Balance at (in millions) March 31, 2020 December 31, 2019 Cost of removal obligations (1) $ 6,593 $ 6,456 Recoveries in excess of AROs (2) 66 393 Public purpose programs (3) 903 817 Employee benefit plans (4) 760 750 Other 929 854 Total long-term regulatory liabilities $ 9,251 $ 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) March 31, 2020 December 31, 2019 Electric distribution $ 213 $ — Electric transmission — 9 Gas distribution and transmission 45 363 Energy procurement 881 901 Public purpose programs 288 209 Other 675 632 Total regulatory balancing accounts receivable $ 2,102 $ 2,114 Payable Balance at (in millions) March 31, 2020 December 31, 2019 Electric distribution $ — $ 31 Electric transmission 148 119 Gas distribution and transmission 74 45 Energy procurement 585 649 Public purpose programs 565 559 Other 473 394 Total regulatory balancing accounts payable $ 1,845 $ 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	3 Months Ended
	Mar. 31, 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., 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”). The DIP Credit Agreement provides for $5.5 billion in senior secured superpriority debtor in possession credit facilities in the form of (i) a revolving credit facility in an aggregate amount of $3.5 billion (the “DIP Revolving Facility”), including a $1.5 billion letter of credit subfacility, (ii) a term loan facility in an aggregate principal amount of $1.5 billion (the “DIP Initial Term Loan Facility”) and (iii) a delayed draw term loan facility in an aggregate principal amount of $500 million (the “DIP Delayed Draw Term Loan Facility,” together with the DIP Revolving Facility and the DIP Initial Term Loan Facility, the “DIP Facilities”), subject to the terms and conditions set forth therein. The DIP Credit Agreement also provides for up to $4.0 billion of incremental facilities in the form of (i) one or more additional tranches of term loans or (ii) one or more increases in the aggregate amount of revolving commitments under the DIP Revolving Facility (together, the “Incremental Facilities”), subject to the terms and conditions set forth therein. The Incremental Facilities are uncommitted and would require approval from the Bankruptcy Court. 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, which motion was granted on an interim basis by the Bankruptcy Court following a hearing on January 31, 2019. As a result of the Bankruptcy Court’s interim approval of the DIP Facilities and the satisfaction of the other conditions thereof, the DIP Credit Agreement became effective on February 1, 2019 and a portion of the DIP Revolving Facility in the amount of $1.5 billion (including $750 million of the letter of credit subfacility) was made available to the Utility. On March 27, 2019, the Bankruptcy Court approved the DIP Facilities on a final basis, authorizing the Utility to borrow up to the remainder of the DIP Revolving Facility (including the remainder of the $1.5 billion letter of credit subfacility), the DIP Initial Term Loan Facility and the DIP Delayed Draw Term Loan Facility, in each case subject to the terms and conditions of the DIP Credit Agreement. Borrowings under the DIP Facilities are senior secured obligations of the Utility, secured by substantially all of the Utility’s assets and entitled to superpriority administrative expense claim status in the Utility’s Chapter 11 Case. The Utility’s obligations under the DIP Facilities are guaranteed by PG&E Corporation, and such guarantee is a senior secured obligation of PG&E Corporation, secured by substantially all of PG&E Corporation’s assets and entitled to superpriority administrative expense claim status in PG&E Corporation’s Chapter 11 Case. On January 29, 2020, the Utility borrowed $500 million under the DIP Delayed Draw Term Loan Facility. The commencement of the Chapter 11 Cases constituted an event of default or termination event with respect to, and caused an automatic and immediate acceleration of the debt outstanding under or in respect of, certain instruments and agreements relating to direct financial obligations of PG&E Corporation and the Utility (the “Accelerated Direct Financial Obligations”). However, any efforts to enforce such payment obligations are automatically stayed as of the Petition Date, and are subject to the applicable provisions of the Bankruptcy Code and orders of the Bankruptcy Court. The material Accelerated Direct Financial Obligations include the Utility’s outstanding senior notes, agreements in respect of certain series of pollution control bonds, and PG&E Corporation’s term loan facility, as well as short-term borrowings under PG&E Corporation’s and the Utility’s revolving credit facilities and the Utility’s term loan facility. For more information, see Note 5 of the Notes to the Consolidated Financial Statements in Item 8 of the 2019 Form 10-K. Debtor-in-Possession Financing The following table summarizes the Utility’s outstanding borrowings and availability under the DIP Facilities at March 31, 2020: (in millions) Termination Aggregate Limit Term Loan Borrowings Revolver Letters of Credit Outstanding Aggregate DIP Facilities December 2020 (1) $ 5,500 $ 2,000 $ — $ 774 $ 2,726 (1) May be extended to December 2021, subject to satisfaction of certain terms and conditions, including payment of a 25 basis point extension fee. Debt The following table summarizes PG&E Corporation’s and the Utility’s outstanding debt subject to compromise: Balance at (in millions) Contractual Interest Rates March 31, 2020 December 31, 2019 Treatment under Plan (1) Debt Subject to Compromise (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 Other borrowings Term Loan - Stated Maturity: 2020 variable rate (4) 350 350 Repaid in cash Total PG&E Corporation Debt Subject to Compromise 650 650 Utility Senior Notes - Stated Maturity: 2020 3.50% 800 800 Exchanged for New Utility Short-Term Notes 2021 3.25% to 4.25% 550 550 Exchanged for New Utility Short-Term Notes 2022 2.45% 400 400 Exchanged for New Utility Short-Term Notes 2023 3.25% to 4.25% 1,175 1,175 Reinstated 2024 through 2028 2.95% to 4.65% 3,850 3,850 Reinstated 2034 through 2040 5.40% to 6.35% 5,700 5,700 Exchanged for New Utility Long-Term Notes 2041 through 2042 3.75% to 4.50% 1,000 1,000 Reinstated 2043 4.60% 375 375 Reinstated 2043 5.13% 500 500 Exchanged for New Utility Long-Term Notes 2044 through 2047 3.95% to 4.75% 3,175 3,175 Reinstated Total Senior notes 17,525 17,525 Pollution Control Bonds - Stated Maturity: Series 2008 F and 2010 E, due 2026 (5) 1.75% 100 100 Repaid in cash Series 2009 A-B, due 2026 (6) variable rate (7) 149 149 Exchanged for New Utility Funded Debt Exchange Notes Series 1996 C, E, F, 1997 B due 2026 (6) variable rate (8) 614 614 Exchanged for New Utility Funded Debt Exchange Notes Total pollution control bonds 863 863 Borrowings under Pre-Petition Credit Facilities Utility Revolving Credit Facilities - Stated Maturity: 2022 (9) variable rate (10) 2,888 2,888 Exchanged for New Utility Funded Debt Exchange Notes Other borrowings: Term Loan - Stated Maturity: 2019 variable rate (11) 250 250 Exchanged for New Utility Funded Debt Exchange Notes Total Borrowings under Pre-Petition Credit Facility Subject to Compromise 3,138 3,138 Total Utility Debt Subject to Compromise 21,526 21,526 Total PG&E Corporation Consolidated Debt Subject to Compromise $ 22,176 $ 22,176 (1) The treatments of debt under the Plan, described in this column relate only to the treatment of principal amounts and not pre-petition or post-petition interest. The New Utility Short-Term Notes, New Utility Long-Term Senior Notes and New Utility Funded Debt Exchange Notes are described in more detail under “Restructuring Support Agreement with the Ad Hoc Noteholder Committee” in Note 2. (2) Debt subject to compromise must be reported at the amounts expected to be allowed by the Bankruptcy Court and the carrying values will be adjusted as claims are approved. Total Debt Subject to Compromise does not include accrued contractual interest of $1 million and $286 million for PG&E Corporation and the Utility, respectively, to the Petition Date. Total Debt Subject to Compromise also does not include post-petition interest of $20 million and $815 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 March 31, 2020, the contractual LIBOR-based interest rate on loans was 2.46%. (4) At March 31, 2020, the contractual LIBOR-based interest rate on the term loan was 2.18%. (5) Pollution Control Bonds series 2008F and 2010E were reissued in June 2017. Although the stated maturity date for both series is 2026, these bonds have a mandatory redemption date of May 31, 2022. (6) Each series of these bonds is supported by a separate direct-pay letter of credit. Following the Utility’s Chapter 11 filing, investors in these bonds drew on the letter of credit facilities. The letter of credit facility supporting the Series 2009 A-B bonds matured on June 5, 2019. In December 2015, the maturity dates of the letter of credit facilities supporting the Series 1996 C, E, F, 1997 B bonds were extended to December 1, 2020. Although the stated maturity date of these bonds is 2026, each series will remain outstanding only if the Utility extends or replaces the letter of credit related to the series or otherwise obtains consent from the issuer to the continuation of the series without a credit facility. (7) At March 31, 2020, the contractual interest rate on the letter of credit facilities supporting these bonds was 6.45%. (8) At March 31, 2020, the contractual interest rate on the letter of credit facilities supporting these bonds ranged from 6.45% to 6.58%. (9) At March 31, 2020, excludes $19 million of undrawn letters of credit. (10) At March 31, 2020, the contractual LIBOR-based interest rate on the loans was 2.26%. (11) At March 31, 2020, the contractual LIBOR-based interest rate on the term loan was 1.58%. Debt Commitments See “Plan of Reorganization, RSA, Equity Backstop Commitments and Debt Commitments Letters” in Note 2 of the Condensed Consolidated Financial Statements above for discussion of the debt commitments.

EQUITY

EQUITY	3 Months Ended
	Mar. 31, 2020
Equity [Abstract]
EQUITY	EQUITY There were no issuances under the PG&E Corporation February 2017 equity distribution agreement for the three months ended March 31, 2020. 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. 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, due to the uncertainty related to the causes of and potential liabilities associated with wildfires. See Wildfire-related Contingencies in Note 10 below. The DIP Credit Agreement includes usual and customary covenants for debtor-in-possession loan agreements of this type, including covenants limiting PG&E Corporation’s and the Utility’s ability to, among other things, declare and pay any dividend or make any other distributions with respect to any of their capital stock. Also, on April 3, 2019, the court overseeing the Utility’s probation issued an order imposing new conditions of probation, including foregoing 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 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. Equity Backstop Commitment s See “Plan of Reorganization, RSA, Equity Backstop Commitments and Debt Commitment Letters” in Note 2 of the Condensed Consolidated Financial Statements above for discussion of the equity backstop commitments.

EARNINGS PER SHARE

EARNINGS PER SHARE	3 Months Ended
	Mar. 31, 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 March 31, (in millions, except per share amounts) 2020 2019 Income available for common shareholders $ 371 $ 136 Weighted average common shares outstanding, basic 529 526 Add incremental shares from assumed conversions: Employee share-based compensation — 1 Chapter 11-related settlements (1) 119 — Weighted average common shares outstanding, diluted 648 527 Total income per common share, diluted $ 0.57 $ 0.25 (1) As discussed in Note 2, the financing sources for the Plan are expected to include (1) one or more PG&E Corporation common stock offerings of up to $9.0 billion and (2) the issuance of new common stock to the Fire Victim Trust. These financing sources along with the Backstop Commitment premium of 119.0 million shares of common stock (which could increase by 19,909,091 additional shares) for the Backstop Commitments will dilute current equity interests if or when such common stock is issued. At March 31, 2020, only the Backstop Commitment premium meets the requirements to be presented as incremental shares in the calculation of diluted income per common share. For each of the periods presented above, the calculation of outstanding common shares on a diluted basis excluded an insignificant amount of options and securities that were antidilutive.

DERIVATIVES

DERIVATIVES	3 Months Ended
	Mar. 31, 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 counter-party. 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 March 31, 2020 December 31, 2019 Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 138,102,835 131,896,159 Options 7,760,000 14,720,000 Electricity (Megawatt-hours) Forwards, Futures and Swaps 49,291,087 18,675,852 Options 4,414,400 — Congestion Revenue Rights (3) 298,648,904 308,467,999 (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 March 31, 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 $ 35 $ (6) $ 11 $ 40 Other noncurrent assets – other 133 — — 133 Current liabilities – other (31) 6 1 (24) Noncurrent liabilities – other (138) — — (138) Total commodity risk $ (1) $ — $ 12 $ 11 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	3 Months Ended
	Mar. 31, 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 March 31, 2020 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 1,717 $ — $ — $ — $ 1,717 Nuclear decommissioning trusts Short-term investments 82 — — — 82 Global equity securities 1,792 — — — 1,792 Fixed-income securities 784 734 — — 1,518 Assets measured at NAV — — — — 17 Total nuclear decommissioning trusts (2) 2,658 734 — — 3,409 Price risk management instruments (Note 8) Electricity — 7 159 5 171 Gas — 2 — — 2 Total price risk management instruments — 9 159 5 173 Rabbi trusts Fixed-income securities — 102 — — 102 Life insurance contracts — 76 — — 76 Total rabbi trusts — 178 — — 178 Long-term disability trust Short-term investments 6 — — — 6 Assets measured at NAV — — — — 157 Total long-term disability trust 6 — — — 163 TOTAL ASSETS $ 4,381 $ 921 $ 159 $ 5 $ 5,640 Liabilities: Price risk management instruments (Note 8) Electricity $ — $ 5 $ 164 $ (7) $ 162 Gas — — — — — TOTAL LIABILITIES $ — $ 5 $ 164 $ (7) $ 162 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $498 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 months ended March 31, 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 at Level 1. Global equity securities primarily include investments in common stock that are valued based on quoted prices in active markets and are classified as Level 1. Fixed-income securities are primarily composed of U.S. government and agency securities, municipal securities, and other fixed-income securities, including corporate debt securities. U.S. government and agency securities primarily consist of U.S. Treasury securities that are classified as Level 1 because the fair value is determined by observable market prices in active markets. A market approach is generally used to estimate the fair value of fixed-income securities classified as Level 2 using evaluated pricing data such as broker quotes, for similar securities adjusted for observable differences. Significant inputs used in the valuation model generally include benchmark yield curves and issuer spreads. The external credit ratings, coupon rate, and maturity of each security are considered in the valuation model, as applicable. Assets Measured at NAV Using Practical Expedient Investments in the nuclear decommissioning trusts and the long-term disability trust that are measured at fair value using the NAV per share practical expedient have not been classified in the fair value hierarchy tables above. The fair value amounts are included in the tables above in order to reconcile to the amounts presented in the 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 The Backstop Commitments are defined as financial instruments and measurable at fair value on each reporting period. PG&E Corporation used both market observable inputs and unobservable data to derive the fair value as of the reporting date. The Backstop Commitments are classified as Level 3. Fair value for the Backstop Commitments as of March 31, 2020, was $0. PG&E Corporation’s fair valuation model calculated both the Backstop Party’s commitment to fund up to $9.0 billion in new common stock as well as PG&E Corporation’s Backstop Commitment premium obligation. The commitment to fund new common stock will cease upon equity offerings to finance the transactions contemplated by the Plan or termination of Backstop Commitments. As of March 31, 2020, PG&E Corporation expects to record approximately $1 billion of expense related to the Backstop Commitment premium in Reorganization items, net for the year ended December 31, 2020. This fair value calculation is subject to change based on fluctuations in the price of PG&E Corporation’s common stock as well as the satisfaction of certain conditions in the Backstop Commitment Letters. 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) March 31, 2020 Fair Value Measurement Assets Liabilities Valuation Unobservable Range (1) / Weighted-Average Price (2) Congestion revenue rights $ 141 $ 45 Market approach CRR auction prices $(45.08) - $20.20 / 0.27 Power purchase agreements $ 18 $ 119 Discounted cash flow Forward prices $9.42 - $57.42 / 32.04 (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 months ended March 31, 2020 and 2019: Price Risk Management Instruments (in millions) 2020 2019 Asset balance as of January 1 $ 5 $ 95 Net realized and unrealized gains: Included in regulatory assets and liabilities or balancing accounts (1) (10) 34 Asset balance as of March 31 $ (5) $ 129 (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 March 31, 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 March 31, 2020 At December 31, 2019 (in millions) Carrying Amount Level 2 Fair Value Carrying Amount Level 2 Fair Value Debt (Note 5) PG&E Corporation (1) $ — $ — $ — $ — Utility (1)(2) 2,000 2,007 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 is $17.2 billion and $17.9 billion as of March 31, 2020 and December 31, 2019, respectively. 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 March 31, 2020 Amortized Total Unrealized Gains Total Unrealized Losses Total Fair Nuclear decommissioning trusts Short-term investments $ 82 $ — $ — $ 82 Global equity securities 652 1,188 (31) 1,809 Fixed-income securities 1,377 155 (14) 1,518 Total (1) $ 2,111 $ 1,343 $ (45) $ 3,409 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 $498 million and $530 million for the periods ended March 31, 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) March 31, 2020 Less than 1 year $ 26 1–5 years 397 5–10 years 408 More than 10 years 687 Total maturities of fixed-income securities $ 1,518 The following table provides a summary of activity for fixed income and equity securities: Three Months Ended March 31, (in millions) 2020 2019 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 533 $ 346 Gross realized gains on securities 18 (34) Gross realized losses on securities (9) 19

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES	3 Months Ended
	Mar. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
WILDFIRE-RELATED CONTINGENCIES	WILDFIRE-RELATED CONTINGENCIESPG&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. Pre-petition Wildfire-Related Claims 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 March 31, 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 corresponds PG&E Corporation’s and the Utility’s best estimate of probable losses and is subject to change based on additional information, including the other factors discussed below. (See “2018 Camp Fire, 2017 Northern California Wildfires and 2015 Butte Fire Accounting Charge” below.) On the Petition Date, all wildfire-related claims were classified as LSTC and all pending litigation was stayed. In addition, the Utility incurred legal and other costs of $34 million and $47 million related to the 2018 Camp fire, the 2017 Northern California wildfires and the 2015 Butte fire during the quarters ended March 31, 2020 and 2019, respectively. 2018 Camp Fire 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. On May 15, 2019, Cal Fire issued a news release announcing the results of its investigation into the cause of the 2018 Camp fire. According to the news release: • Cal Fire determined that the 2018 Camp fire was caused by electrical transmission lines owned and operated by the Utility near Pulga, California. • Cal Fire identified a second ignition site and stated that the second fire was consumed by the original fire which started earlier near Pulga, California. Cal Fire stated that the cause of the second fire was determined to be “vegetation into electrical distribution lines owned and operated by” the Utility. As described under the heading “District Attorneys’ Offices’ Investigations” below, the 2018 Camp fire was the subject of a criminal investigation, which has been settled, as to PG&E Corporation and the Utility, by the parties, subject to court approvals from the Bankruptcy Court, which was granted as of April 14, 2020, and the Butte County Superior Court, currently scheduled to occur on or about May 26, 2020. As of the date of this filing, Cal Fire’s investigation report has not been shared with PG&E Corporation or the Utility. PG&E Corporation and the Utility have accepted Cal Fire’s determination that the 2018 Camp fire ignited at the first ignition site. PG&E Corporation and the Utility have not been able to form a conclusion as to whether a second fire ignited as a result of vegetation contact with the Utility’s facilities. PG&E Corporation and the Utility have not yet had access to all of the evidence collected by Cal Fire as part of its investigation or to the investigation report prepared by Cal Fire. Further, the CPUC’s SED also conducted investigations into whether the Utility committed civil violations in connection with the 2018 Camp fire. On November 26, 2019, the SED concluded its investigation into the 2018 Camp fire and released a report alleging certain violations of state law and CPUC regulations. See “Order Instituting an Investigation into the 2017 Northern California Wildfires and the 2018 Camp Fire” in Note 11 for a description of these proceedings, including the alleged violations in connection with the 2018 Camp fire. 2017 Northern California Wildfires Background 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. Cal Fire has investigated the causes of the 2017 Northern California wildfires and made the following determinations: • the Utility’s equipment was involved in causing 20 wildfires (the La Porte, McCourtney, Lobo, Honey, Redwood, Sulphur, Cherokee, 37, Blue, Norrbom, Adobe, Partrick, Pythian, Nuns, Pocket, Atlas, Cascade, Pressley, Point and Youngs fires); and • the Tubbs fire was caused by a private electrical system adjacent to a residential structure. As described under the heading “District Attorney’s Offices’ Investigations” below, certain of the 2017 Northern California wildfires were the subject of criminal investigations, which have been settled or resulted in PG&E Corporation and the Utility being informed by the applicable district attorney’s office of a decision not to prosecute. The SED also conducted investigations into whether the Utility committed civil violations in connection with the 2017 Northern California wildfires. See “Order Instituting an Investigation into the 2017 Northern California Wildfires and the 2018 Camp Fire” in Note 11 for a description of these proceedings, including the alleged violations in connection with the 2017 Northern California wildfires. Third-Party Claims, Investigations and Other Proceedings Related to the 2018 Camp Fire and 2017 Northern California Wildfires If the Utility’s facilities, such as its electric distribution and transmission lines, are determined to be the substantial cause of one or more fires, 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, including in connection with SB 901.) On October 25, 2019, PG&E Corporation and the Utility submitted a brief to the Bankruptcy Court challenging the application of inverse condemnation to California’s investor-owned utilities, including the Utility. The Bankruptcy Court heard argument regarding PG&E Corporation’s and the Utility’s motion on November 19, 2019. On December 3, 2019, the Bankruptcy Court entered an order holding that the doctrine of inverse condemnation applied to California’s investor-owned utilities, including the Utility, and certifying the decision for direct appeal to the U.S. Court of Appeals for the Ninth Circuit. PG&E Corporation and the Utility have appealed this decision; however, as of the date of this filing, this appeal was stayed upon request of PG&E Corporation and the Utility due to, among other things, the settlement of fire claims embodied in the Public Entity PSA’s, TCC RSA and Subrogation RSA. 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. Further, the Utility could be subject to material fines, penalties, or restitution orders if the CPUC or any law enforcement agency were to bring an enforcement action, including, if the Plea Agreement is terminated, a criminal proceeding, and it were determined that the Utility had failed to comply with applicable laws and regulations. As of January 28, 2019, before the automatic stay arising as a result of the filing of the Chapter 11 Cases, PG&E Corporation and the Utility were aware of approximately 100 complaints on behalf of at least 4,200 plaintiffs related to the 2018 Camp fire, nine of which sought to be certified as class actions. The pending civil litigation against PG&E Corporation and the Utility related to the 2018 Camp fire, which is currently stayed as a result of the commencement of the Chapter 11 Cases, included claims under multiple theories of liability, including, but not limited to, inverse condemnation, trespass, private nuisance, public nuisance, negligence, negligence per se, negligent interference with prospective economic advantage, negligent infliction of emotional distress, premises liability, violations of the Public Utilities Code, violations of the Health & Safety Code, malice and false advertising in violation of the California Business and Professions Code. The plaintiffs principally asserted that PG&E Corporation’s and the Utility’s alleged failure to maintain and repair their distribution and transmission lines and failure to properly maintain the vegetation surrounding such lines were the causes of the 2018 Camp fire. The plaintiffs sought damages and remedies that include wrongful death, personal injury, property damage, evacuation costs, medical expenses, establishment of a class action medical monitoring fund, punitive damages, attorneys’ fees and other damages. As of January 28, 2019, before the automatic stay arising as a result of the filing of the Chapter 11 Cases, PG&E Corporation and the Utility were aware of approximately 750 complaints on behalf of at least 3,800 plaintiffs related to the 2017 Northern California wildfires, five of which sought to be certified as class actions. These cases were coordinated in the San Francisco County Superior Court. As of the Petition Date, the coordinated litigation was in the early stages of discovery. A trial with respect to the Atlas fire was scheduled to begin on September 23, 2019. The pending civil litigation against PG&E Corporation and the Utility related to the 2017 Northern California wildfires included claims under multiple theories of liability, including, but not limited to, inverse condemnation, trespass, private nuisance and negligence. This litigation, including the trial date with respect to the Atlas fire, currently is stayed as a result of the commencement of the Chapter 11 Cases. The plaintiffs principally asserted that PG&E Corporation’s and the Utility’s alleged failure to maintain and repair their distribution and transmission lines and failure to properly maintain the vegetation surrounding such lines were the causes of the 2017 Northern California wildfires. The plaintiffs sought damages and remedies that include wrongful death, personal injury, property damage, evacuation costs, medical expenses, punitive damages, attorneys’ fees and other damages. 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. Insurance carriers who have made payments to their insureds for property damage arising out of the 2017 Northern California wildfires filed 52 subrogation complaints in the San Francisco County Superior Court and the Sonoma County Superior Court as of January 28, 2019. These complaints allege, among other things, negligence, inverse condemnation, trespass and nuisance. The allegations are similar to the ones made by individual plaintiffs. As of January 28, 2019, before the automatic stay arising as a result of the filing of the Chapter 11 Cases, insurance carriers filed 39 similar subrogation complaints with respect to the 2018 Camp fire in the Sacramento County Superior Court and the Butte County Superior Court. 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. Various government entities, including Yuba, Nevada, Lake, Mendocino, Napa and Sonoma Counties and the Cities of Santa Rosa and Clearlake, also asserted claims against PG&E Corporation and the Utility based on the damages that these government entities allegedly suffered as a result of the 2017 Northern California wildfires. Such alleged damages included, among other things, loss of natural resources, loss of public parks, property damages and fire suppression costs. The causes of action and allegations are similar to the ones made by individual plaintiffs and the insurance carriers. With respect to the 2018 Camp fire, Butte County has filed similar claims against PG&E Corporation and the Utility. 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, the Bankruptcy Court must ultimately approve the Plan that incorporates the terms of the PSAs. FEMA has filed proofs of claim in the Chapter 11 Cases in the amount of $1.2 billion in connection with the 2017 Northern California wildfires and $2.6 billion in connection with the 2018 Camp fire. FEMA has objected to the classification of their claims under the Plan as Fire Victim Claims and has indicated that it intends to seek to have its claims classified separately from the Fire Victim Claims. In addition, Cal Fire has filed proofs of claim in the Chapter 11 Cases in the amount of $133 million in connection with the 2017 Northern California wildfires and specifying at least $110 million in connection with the 2018 Camp fire. The OES has filed proofs of claim in the amount of $347 million in connection with the 2017 Northern California wildfires and $2.3 billion in connection with the 2018 Camp fire. The California Department of Transportation has filed proofs of claim in the Chapter 11 Cases in the amount of $217 million in connection with the 2018 Camp fire. Certain other Federal, state and local entities (that are not Supporting Public Entities) have filed proofs of claim in the Chapter 11 Cases in connection with the 2017 Northern California wildfires and the 2018 Camp fire asserting total claims in the amount of $503 million. Proofs of claim have also been filed for unspecified amounts to be determined at a later time. On December 12, 2019, the TCC filed an objection to the claims filed by OES in which it argued that the Bankruptcy Court should disallow the OES claims. On January 9, 2020, the TCC filed a supplement to its objection in which it also objected to the claims filed by FEMA. On February 5, 2020, PG&E Corporation and the Utility joined in the TCC’s objection to the OES and FEMA claims. On February 12, 2020, a number of individuals and businesses who hold wildfire-related claims in connection with the 2015 Butte fire, 2017 Northern California wildfires and 2018 Camp fire, as well as certain preference plaintiffs (the “Tubbs Preference Plaintiffs”), joined in the TCC’s objection to the OES and FEMA claims. Also on February 12, 2020, OES and FEMA filed oppositions to the TCC’s objection. On February 26, 2020, the Bankruptcy Court heard argument over the TCC’s and PG&E Corporation’s and the Utility’s legal objections to claims filed by FEMA and Cal OES. On February 27, 2020, the TCC, the Consenting Fire Claimant Professionals (as defined in the Plan), FEMA and certain other federal agencies, the OES and certain other state agencies, the Debtors, and the Shareholder Proponents participated in a mediation in San Francisco, California in an effort to resolve the aforementioned claims. 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 will be allowed at $1 billion, channeled to the Fire Victim Trust, and fully subordinated and 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 will be withdrawn with prejudice; Cal Fire’s Fire Claims will be allowed at $115.3 million, 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 will be 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 (as defined below) 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, will 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 agreements on April 26, 2020. A hearing before the Bankruptcy Court to consider approval of the agreements is currently scheduled for May 12, 2020. As described in Note 2, on July 1, 2019, the Bankruptcy Court entered an order approving the Bar Date of October 21, 2019, at 5:00 p.m. (Pacific Time) for filing claims against PG&E Corporation and the Utility relating to the period prior to the Petition Date, including claims in connection with the 2018 Camp fire and the 2017 Northern California wildfires. On November 11, 2019, the Bankruptcy Court entered an order approving a stipulation between PG&E Corporation and the Utility and the TCC to extend the Bar Date for unfiled, non-governmental fire claimants to December 31, 2019, at 5:00 p.m. (Pacific Time). See “Potential Claims” in Note 2 above. Regardless of any determinations of cause by Cal Fire with respect to any pre-petition fire, ultimately PG&E Corporation’s and the Utility’s liability will be determined through the Chapter 11 process (including the settlement agreements described below), regulatory proceedings and any potential enforcement proceedings. The timing and outcome of these and other potential proceedings are uncertain. Proceeding in San Francisco County Superior Court for Certain Tubbs Fire-Related Claims (the “Tubbs Trial”) In connection with the TCC RSA, on December 26, 2019, the San Francisco Superior Court entered an order vacating all dates and deadlines in the Tubbs Trial and scheduled a hearing for March 2, 2020 to show cause regarding dismissal of the Tubbs Trial. On February 28, 2020, at the request of the Plaintiffs, the Court continued the hearing on the order to show cause to July 27, 2020. On January 6, 2020, in accordance with the terms of the TCC RSA, PG&E Corporation and the Utility filed a motion with the Bankruptcy Court seeking authority to enter into settlement agreements settling and liquidating the claims asserted against PG&E Corporation and the Utility by each of the Tubbs Preference Plaintiffs. On January 30, 2020, the Bankruptcy Court issued an order granting PG&E Corporation and the Utility’s motion to enter into settlement agreements with each of the Tubbs Preference Plaintiffs (the “Tubbs Preference Settlements”). The Tubbs Preference Settlements will be channeled through the Fire Victim Trust. Wildfire Claims Estimation Proceeding in the U.S. District Court for the Northern District of California (the “Estimation Proceeding”) On July 18, 2019, PG&E Corporation and the Utility filed a motion with the Bankruptcy Court for entry of an order establishing procedures and schedules for the estimation of PG&E Corporation’s and the Utility’s aggregate liability for certain claims arising out of the 2018 Camp fire, the 2017 Northern California wildfires and the 2015 Butte fire. On August 21, 2019, the Bankruptcy Court issued recommendations to the District Court recommending the District Court order the partial withdrawal of the reference of the section 502(c) estimation of unliquidated claims arising from the 2018 Camp fire and the 2017 Northern California wildfires. On August 23, 2019, the District Court issued an order adopting the recommendation of the Bankruptcy Court in full and ordering that the reference to the Bankruptcy Court be withdrawn in part. On October 9, 2019, the District Court issued an initial order for the estimation hearings to begin on February 18, 2020 and conclude on February 28, 2020, with the possibility of an additional week of hearings if warranted. In connection with the TCC RSA, on December 20, 2019, the District Court entered an order staying the Estimation Proceeding and vacating the February 18, 2020 hearing and all pre-hearing dates. Under section 502(c) and pursuant to the terms of the TCC RSA, PG&E Corporation and the Utility filed a motion in the District Court on March 20, 2020 requesting that the District Court estimate the aggregate liability of the Fire Victim Claims at $13.5 billion—the amount the parties agreed to in the TCC RSA. Certain parties, including the TCC, objected to the motion arguing, among things, that the District Court needs to clarify certain provisions of the TCC RSA. PG&E Corporation and the Utility filed a reply to the objection on April 10, 2020, and the District Court held a status conference on April 16, 2020. The next status conference is set for May 18, 2020. A hearing on the motion is set for May 21, 2020. 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 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”). PG&E Corporation and the Utility have entered into a PSA with each of the following public entities or groups of public entities, as applicable: • the City of Clearlake, the City of Napa, the City of Santa Rosa, the County of Lake, the Lake County Sanitation District, the County of Mendocino, Napa County, the County of Nevada, the County of Sonoma, the Sonoma County Agricultural Preservation and Open Space District, the Sonoma County Community Development Commission, the Sonoma County Water Agency, the Sonoma Valley County Sanitation District and the County of Yuba (collectively, the “2017 Northern California Wildfire Public Entities”); • the Town of Paradise; • the County of Butte; • the Paradise Recreation & Park District; • the County of Yuba; and • the Calaveras County Water District. For purposes of each PSA, the local public entities that are party to such PSA are referred to herein as “Supporting Public Entities.” Each PSA provides that the Plan will include, among other things, the following elements: • following the effective date of the Plan, PG&E Corporation and the Utility will remit a Settlement Amount (as defined below) in the amount set forth below to the applicable Supporting Public Entities in full and final satisfaction and discharge of their Public Entity Wildfire Claims, and • subject to the Supporting Public Entities voting affirmatively to accept the Plan, following the effective date of the Plan, PG&E Corporation and the Utility will create and promptly fund $10.0 million to a segregated 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”). The “Settlement Amount” set forth in each PSA is as follows: • for the 2017 Northern California Wildfire Public Entities, $415.0 million (which amount will be allocated among such entities), • for the Town of Paradise, $270.0 million, • for the County of Butte, $252.0 million, • for the Paradise Recreation & Park District, $47.5 million, • for the County of Yuba, $12.5 million, and • for the Calaveras County Water District, $3.0 million. Each PSA provides that, subject to certain terms and conditions, the Supporting Public Entities will support the Plan with respect to its treatment of their respective Public Entity Wildfire Claims, including by voting to accept the Plan in the Chapter 11 Cases. Each PSA may be terminated by the applicable Supporting Public Entities under certain circumstances, including: • if the Federal Emergency Management Agency or the OES fails to agree that no reimbursement is required from the Supporting Public Entities on account of assistance rendered by either agency in connection with the wildfires noted above, and • by any individual Supporting Public Entity, if a material amount of Third Party Claims is filed against such Supporting Public Entity and such Third Party Claims are not released pursuant to the Plan. Each PSA may be terminated by PG&E Corporation and the Utility under certain circumstances, including if: • PG&E Corporation and the Utility do not obtain the consent, or the waiver of the lack of consent as a defense, of their insurance carriers for the policy years 2017 and 2018, • the Board of Directors of either PG&E Corporation or the Utility determines in good faith that continued performance under the PSA would be inconsistent with the exercise of its fiduciary duties, and • any Supporting Public Entity terminates a PSA, in which case PG&E Corporation and the Utility may terminate any other PSA. 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. The Subrogation RSA provides that, subject to certain terms and conditions (including that PG&E Corporation and the Utility remain solvent), the Consenting Subrogation Creditors will support the Plan with respect to its treatment of the Subrogation Claims, including by voting their Subrogation Claims to accept the Plan in the Chapter 11 Cases. On September 24, 2019, PG&E Corporation and the Utility filed a motion with the Bankruptcy Court seeking authority to enter into, and perform under, the Subrogation RSA and approving the terms of the settlement contemplated under the Subrogation RSA. On December 19, 2019, the Bankruptcy Court entered an order approving the Subrogation RSA. The Subrogation RSA will automatically terminate if (i) the Plan is not confirmed by June 30, 2020 (or such later date as may be authorized by any amendment to AB 1054) or (ii) the Effective Date does not occur prior to December 31, 2020 (or six months following the deadline for confirmation of the Plan if such deadline is extended by any amendment to AB 1054). The Subrogation RSA may be terminated by any Consenting S

OTHER CONTINGENCIES AND COMMITM

OTHER CONTINGENCIES AND COMMITMENTS	3 Months Ended
	Mar. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
OTHER CONTINGENCIES AND COMMITMENTS	WILDFIRE-RELATED CONTINGENCIESPG&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. Pre-petition Wildfire-Related Claims 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 March 31, 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 corresponds PG&E Corporation’s and the Utility’s best estimate of probable losses and is subject to change based on additional information, including the other factors discussed below. (See “2018 Camp Fire, 2017 Northern California Wildfires and 2015 Butte Fire Accounting Charge” below.) On the Petition Date, all wildfire-related claims were classified as LSTC and all pending litigation was stayed. In addition, the Utility incurred legal and other costs of $34 million and $47 million related to the 2018 Camp fire, the 2017 Northern California wildfires and the 2015 Butte fire during the quarters ended March 31, 2020 and 2019, respectively. 2018 Camp Fire 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. On May 15, 2019, Cal Fire issued a news release announcing the results of its investigation into the cause of the 2018 Camp fire. According to the news release: • Cal Fire determined that the 2018 Camp fire was caused by electrical transmission lines owned and operated by the Utility near Pulga, California. • Cal Fire identified a second ignition site and stated that the second fire was consumed by the original fire which started earlier near Pulga, California. Cal Fire stated that the cause of the second fire was determined to be “vegetation into electrical distribution lines owned and operated by” the Utility. As described under the heading “District Attorneys’ Offices’ Investigations” below, the 2018 Camp fire was the subject of a criminal investigation, which has been settled, as to PG&E Corporation and the Utility, by the parties, subject to court approvals from the Bankruptcy Court, which was granted as of April 14, 2020, and the Butte County Superior Court, currently scheduled to occur on or about May 26, 2020. As of the date of this filing, Cal Fire’s investigation report has not been shared with PG&E Corporation or the Utility. PG&E Corporation and the Utility have accepted Cal Fire’s determination that the 2018 Camp fire ignited at the first ignition site. PG&E Corporation and the Utility have not been able to form a conclusion as to whether a second fire ignited as a result of vegetation contact with the Utility’s facilities. PG&E Corporation and the Utility have not yet had access to all of the evidence collected by Cal Fire as part of its investigation or to the investigation report prepared by Cal Fire. Further, the CPUC’s SED also conducted investigations into whether the Utility committed civil violations in connection with the 2018 Camp fire. On November 26, 2019, the SED concluded its investigation into the 2018 Camp fire and released a report alleging certain violations of state law and CPUC regulations. See “Order Instituting an Investigation into the 2017 Northern California Wildfires and the 2018 Camp Fire” in Note 11 for a description of these proceedings, including the alleged violations in connection with the 2018 Camp fire. 2017 Northern California Wildfires Background 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. Cal Fire has investigated the causes of the 2017 Northern California wildfires and made the following determinations: • the Utility’s equipment was involved in causing 20 wildfires (the La Porte, McCourtney, Lobo, Honey, Redwood, Sulphur, Cherokee, 37, Blue, Norrbom, Adobe, Partrick, Pythian, Nuns, Pocket, Atlas, Cascade, Pressley, Point and Youngs fires); and • the Tubbs fire was caused by a private electrical system adjacent to a residential structure. As described under the heading “District Attorney’s Offices’ Investigations” below, certain of the 2017 Northern California wildfires were the subject of criminal investigations, which have been settled or resulted in PG&E Corporation and the Utility being informed by the applicable district attorney’s office of a decision not to prosecute. The SED also conducted investigations into whether the Utility committed civil violations in connection with the 2017 Northern California wildfires. See “Order Instituting an Investigation into the 2017 Northern California Wildfires and the 2018 Camp Fire” in Note 11 for a description of these proceedings, including the alleged violations in connection with the 2017 Northern California wildfires. Third-Party Claims, Investigations and Other Proceedings Related to the 2018 Camp Fire and 2017 Northern California Wildfires If the Utility’s facilities, such as its electric distribution and transmission lines, are determined to be the substantial cause of one or more fires, 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, including in connection with SB 901.) On October 25, 2019, PG&E Corporation and the Utility submitted a brief to the Bankruptcy Court challenging the application of inverse condemnation to California’s investor-owned utilities, including the Utility. The Bankruptcy Court heard argument regarding PG&E Corporation’s and the Utility’s motion on November 19, 2019. On December 3, 2019, the Bankruptcy Court entered an order holding that the doctrine of inverse condemnation applied to California’s investor-owned utilities, including the Utility, and certifying the decision for direct appeal to the U.S. Court of Appeals for the Ninth Circuit. PG&E Corporation and the Utility have appealed this decision; however, as of the date of this filing, this appeal was stayed upon request of PG&E Corporation and the Utility due to, among other things, the settlement of fire claims embodied in the Public Entity PSA’s, TCC RSA and Subrogation RSA. 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. Further, the Utility could be subject to material fines, penalties, or restitution orders if the CPUC or any law enforcement agency were to bring an enforcement action, including, if the Plea Agreement is terminated, a criminal proceeding, and it were determined that the Utility had failed to comply with applicable laws and regulations. As of January 28, 2019, before the automatic stay arising as a result of the filing of the Chapter 11 Cases, PG&E Corporation and the Utility were aware of approximately 100 complaints on behalf of at least 4,200 plaintiffs related to the 2018 Camp fire, nine of which sought to be certified as class actions. The pending civil litigation against PG&E Corporation and the Utility related to the 2018 Camp fire, which is currently stayed as a result of the commencement of the Chapter 11 Cases, included claims under multiple theories of liability, including, but not limited to, inverse condemnation, trespass, private nuisance, public nuisance, negligence, negligence per se, negligent interference with prospective economic advantage, negligent infliction of emotional distress, premises liability, violations of the Public Utilities Code, violations of the Health & Safety Code, malice and false advertising in violation of the California Business and Professions Code. The plaintiffs principally asserted that PG&E Corporation’s and the Utility’s alleged failure to maintain and repair their distribution and transmission lines and failure to properly maintain the vegetation surrounding such lines were the causes of the 2018 Camp fire. The plaintiffs sought damages and remedies that include wrongful death, personal injury, property damage, evacuation costs, medical expenses, establishment of a class action medical monitoring fund, punitive damages, attorneys’ fees and other damages. As of January 28, 2019, before the automatic stay arising as a result of the filing of the Chapter 11 Cases, PG&E Corporation and the Utility were aware of approximately 750 complaints on behalf of at least 3,800 plaintiffs related to the 2017 Northern California wildfires, five of which sought to be certified as class actions. These cases were coordinated in the San Francisco County Superior Court. As of the Petition Date, the coordinated litigation was in the early stages of discovery. A trial with respect to the Atlas fire was scheduled to begin on September 23, 2019. The pending civil litigation against PG&E Corporation and the Utility related to the 2017 Northern California wildfires included claims under multiple theories of liability, including, but not limited to, inverse condemnation, trespass, private nuisance and negligence. This litigation, including the trial date with respect to the Atlas fire, currently is stayed as a result of the commencement of the Chapter 11 Cases. The plaintiffs principally asserted that PG&E Corporation’s and the Utility’s alleged failure to maintain and repair their distribution and transmission lines and failure to properly maintain the vegetation surrounding such lines were the causes of the 2017 Northern California wildfires. The plaintiffs sought damages and remedies that include wrongful death, personal injury, property damage, evacuation costs, medical expenses, punitive damages, attorneys’ fees and other damages. 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. Insurance carriers who have made payments to their insureds for property damage arising out of the 2017 Northern California wildfires filed 52 subrogation complaints in the San Francisco County Superior Court and the Sonoma County Superior Court as of January 28, 2019. These complaints allege, among other things, negligence, inverse condemnation, trespass and nuisance. The allegations are similar to the ones made by individual plaintiffs. As of January 28, 2019, before the automatic stay arising as a result of the filing of the Chapter 11 Cases, insurance carriers filed 39 similar subrogation complaints with respect to the 2018 Camp fire in the Sacramento County Superior Court and the Butte County Superior Court. 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. Various government entities, including Yuba, Nevada, Lake, Mendocino, Napa and Sonoma Counties and the Cities of Santa Rosa and Clearlake, also asserted claims against PG&E Corporation and the Utility based on the damages that these government entities allegedly suffered as a result of the 2017 Northern California wildfires. Such alleged damages included, among other things, loss of natural resources, loss of public parks, property damages and fire suppression costs. The causes of action and allegations are similar to the ones made by individual plaintiffs and the insurance carriers. With respect to the 2018 Camp fire, Butte County has filed similar claims against PG&E Corporation and the Utility. 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, the Bankruptcy Court must ultimately approve the Plan that incorporates the terms of the PSAs. FEMA has filed proofs of claim in the Chapter 11 Cases in the amount of $1.2 billion in connection with the 2017 Northern California wildfires and $2.6 billion in connection with the 2018 Camp fire. FEMA has objected to the classification of their claims under the Plan as Fire Victim Claims and has indicated that it intends to seek to have its claims classified separately from the Fire Victim Claims. In addition, Cal Fire has filed proofs of claim in the Chapter 11 Cases in the amount of $133 million in connection with the 2017 Northern California wildfires and specifying at least $110 million in connection with the 2018 Camp fire. The OES has filed proofs of claim in the amount of $347 million in connection with the 2017 Northern California wildfires and $2.3 billion in connection with the 2018 Camp fire. The California Department of Transportation has filed proofs of claim in the Chapter 11 Cases in the amount of $217 million in connection with the 2018 Camp fire. Certain other Federal, state and local entities (that are not Supporting Public Entities) have filed proofs of claim in the Chapter 11 Cases in connection with the 2017 Northern California wildfires and the 2018 Camp fire asserting total claims in the amount of $503 million. Proofs of claim have also been filed for unspecified amounts to be determined at a later time. On December 12, 2019, the TCC filed an objection to the claims filed by OES in which it argued that the Bankruptcy Court should disallow the OES claims. On January 9, 2020, the TCC filed a supplement to its objection in which it also objected to the claims filed by FEMA. On February 5, 2020, PG&E Corporation and the Utility joined in the TCC’s objection to the OES and FEMA claims. On February 12, 2020, a number of individuals and businesses who hold wildfire-related claims in connection with the 2015 Butte fire, 2017 Northern California wildfires and 2018 Camp fire, as well as certain preference plaintiffs (the “Tubbs Preference Plaintiffs”), joined in the TCC’s objection to the OES and FEMA claims. Also on February 12, 2020, OES and FEMA filed oppositions to the TCC’s objection. On February 26, 2020, the Bankruptcy Court heard argument over the TCC’s and PG&E Corporation’s and the Utility’s legal objections to claims filed by FEMA and Cal OES. On February 27, 2020, the TCC, the Consenting Fire Claimant Professionals (as defined in the Plan), FEMA and certain other federal agencies, the OES and certain other state agencies, the Debtors, and the Shareholder Proponents participated in a mediation in San Francisco, California in an effort to resolve the aforementioned claims. 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 will be allowed at $1 billion, channeled to the Fire Victim Trust, and fully subordinated and 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 will be withdrawn with prejudice; Cal Fire’s Fire Claims will be allowed at $115.3 million, 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 will be 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 (as defined below) 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, will 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 agreements on April 26, 2020. A hearing before the Bankruptcy Court to consider approval of the agreements is currently scheduled for May 12, 2020. As described in Note 2, on July 1, 2019, the Bankruptcy Court entered an order approving the Bar Date of October 21, 2019, at 5:00 p.m. (Pacific Time) for filing claims against PG&E Corporation and the Utility relating to the period prior to the Petition Date, including claims in connection with the 2018 Camp fire and the 2017 Northern California wildfires. On November 11, 2019, the Bankruptcy Court entered an order approving a stipulation between PG&E Corporation and the Utility and the TCC to extend the Bar Date for unfiled, non-governmental fire claimants to December 31, 2019, at 5:00 p.m. (Pacific Time). See “Potential Claims” in Note 2 above. Regardless of any determinations of cause by Cal Fire with respect to any pre-petition fire, ultimately PG&E Corporation’s and the Utility’s liability will be determined through the Chapter 11 process (including the settlement agreements described below), regulatory proceedings and any potential enforcement proceedings. The timing and outcome of these and other potential proceedings are uncertain. Proceeding in San Francisco County Superior Court for Certain Tubbs Fire-Related Claims (the “Tubbs Trial”) In connection with the TCC RSA, on December 26, 2019, the San Francisco Superior Court entered an order vacating all dates and deadlines in the Tubbs Trial and scheduled a hearing for March 2, 2020 to show cause regarding dismissal of the Tubbs Trial. On February 28, 2020, at the request of the Plaintiffs, the Court continued the hearing on the order to show cause to July 27, 2020. On January 6, 2020, in accordance with the terms of the TCC RSA, PG&E Corporation and the Utility filed a motion with the Bankruptcy Court seeking authority to enter into settlement agreements settling and liquidating the claims asserted against PG&E Corporation and the Utility by each of the Tubbs Preference Plaintiffs. On January 30, 2020, the Bankruptcy Court issued an order granting PG&E Corporation and the Utility’s motion to enter into settlement agreements with each of the Tubbs Preference Plaintiffs (the “Tubbs Preference Settlements”). The Tubbs Preference Settlements will be channeled through the Fire Victim Trust. Wildfire Claims Estimation Proceeding in the U.S. District Court for the Northern District of California (the “Estimation Proceeding”) On July 18, 2019, PG&E Corporation and the Utility filed a motion with the Bankruptcy Court for entry of an order establishing procedures and schedules for the estimation of PG&E Corporation’s and the Utility’s aggregate liability for certain claims arising out of the 2018 Camp fire, the 2017 Northern California wildfires and the 2015 Butte fire. On August 21, 2019, the Bankruptcy Court issued recommendations to the District Court recommending the District Court order the partial withdrawal of the reference of the section 502(c) estimation of unliquidated claims arising from the 2018 Camp fire and the 2017 Northern California wildfires. On August 23, 2019, the District Court issued an order adopting the recommendation of the Bankruptcy Court in full and ordering that the reference to the Bankruptcy Court be withdrawn in part. On October 9, 2019, the District Court issued an initial order for the estimation hearings to begin on February 18, 2020 and conclude on February 28, 2020, with the possibility of an additional week of hearings if warranted. In connection with the TCC RSA, on December 20, 2019, the District Court entered an order staying the Estimation Proceeding and vacating the February 18, 2020 hearing and all pre-hearing dates. Under section 502(c) and pursuant to the terms of the TCC RSA, PG&E Corporation and the Utility filed a motion in the District Court on March 20, 2020 requesting that the District Court estimate the aggregate liability of the Fire Victim Claims at $13.5 billion—the amount the parties agreed to in the TCC RSA. Certain parties, including the TCC, objected to the motion arguing, among things, that the District Court needs to clarify certain provisions of the TCC RSA. PG&E Corporation and the Utility filed a reply to the objection on April 10, 2020, and the District Court held a status conference on April 16, 2020. The next status conference is set for May 18, 2020. A hearing on the motion is set for May 21, 2020. 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 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”). PG&E Corporation and the Utility have entered into a PSA with each of the following public entities or groups of public entities, as applicable: • the City of Clearlake, the City of Napa, the City of Santa Rosa, the County of Lake, the Lake County Sanitation District, the County of Mendocino, Napa County, the County of Nevada, the County of Sonoma, the Sonoma County Agricultural Preservation and Open Space District, the Sonoma County Community Development Commission, the Sonoma County Water Agency, the Sonoma Valley County Sanitation District and the County of Yuba (collectively, the “2017 Northern California Wildfire Public Entities”); • the Town of Paradise; • the County of Butte; • the Paradise Recreation & Park District; • the County of Yuba; and • the Calaveras County Water District. For purposes of each PSA, the local public entities that are party to such PSA are referred to herein as “Supporting Public Entities.” Each PSA provides that the Plan will include, among other things, the following elements: • following the effective date of the Plan, PG&E Corporation and the Utility will remit a Settlement Amount (as defined below) in the amount set forth below to the applicable Supporting Public Entities in full and final satisfaction and discharge of their Public Entity Wildfire Claims, and • subject to the Supporting Public Entities voting affirmatively to accept the Plan, following the effective date of the Plan, PG&E Corporation and the Utility will create and promptly fund $10.0 million to a segregated 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”). The “Settlement Amount” set forth in each PSA is as follows: • for the 2017 Northern California Wildfire Public Entities, $415.0 million (which amount will be allocated among such entities), • for the Town of Paradise, $270.0 million, • for the County of Butte, $252.0 million, • for the Paradise Recreation & Park District, $47.5 million, • for the County of Yuba, $12.5 million, and • for the Calaveras County Water District, $3.0 million. Each PSA provides that, subject to certain terms and conditions, the Supporting Public Entities will support the Plan with respect to its treatment of their respective Public Entity Wildfire Claims, including by voting to accept the Plan in the Chapter 11 Cases. Each PSA may be terminated by the applicable Supporting Public Entities under certain circumstances, including: • if the Federal Emergency Management Agency or the OES fails to agree that no reimbursement is required from the Supporting Public Entities on account of assistance rendered by either agency in connection with the wildfires noted above, and • by any individual Supporting Public Entity, if a material amount of Third Party Claims is filed against such Supporting Public Entity and such Third Party Claims are not released pursuant to the Plan. Each PSA may be terminated by PG&E Corporation and the Utility under certain circumstances, including if: • PG&E Corporation and the Utility do not obtain the consent, or the waiver of the lack of consent as a defense, of their insurance carriers for the policy years 2017 and 2018, • the Board of Directors of either PG&E Corporation or the Utility determines in good faith that continued performance under the PSA would be inconsistent with the exercise of its fiduciary duties, and • any Supporting Public Entity terminates a PSA, in which case PG&E Corporation and the Utility may terminate any other PSA. 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. The Subrogation RSA provides that, subject to certain terms and conditions (including that PG&E Corporation and the Utility remain solvent), the Consenting Subrogation Creditors will support the Plan with respect to its treatment of the Subrogation Claims, including by voting their Subrogation Claims to accept the Plan in the Chapter 11 Cases. On September 24, 2019, PG&E Corporation and the Utility filed a motion with the Bankruptcy Court seeking authority to enter into, and perform under, the Subrogation RSA and approving the terms of the settlement contemplated under the Subrogation RSA. On December 19, 2019, the Bankruptcy Court entered an order approving the Subrogation RSA. The Subrogation RSA will automatically terminate if (i) the Plan is not confirmed by June 30, 2020 (or such later date as may be authorized by any amendment to AB 1054) or (ii) the Effective Date does not occur prior to December 31, 2020 (or six months following the deadline for confirmation of the Plan if such deadline is extended by any amendment to AB 1054). The Subrogation RSA may be terminated by any Consenting S

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	3 Months Ended
	Mar. 31, 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 wildfire-related liabilities, regulatory assets and liabilities, legal and regulatory contingencies, insurance receivables, environmental remediation liabilities, AROs, pension and other post-retirement benefit plan obligations, and the valuation of LSTC. 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 March 31, 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 March 31, 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 its 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. 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. The ASU will be effective for PG&E Corporation and the Utility in 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. 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. The ASU will be effective for PG&E Corporation and the Utility before December 31, 2022. PG&E Corporation and the Utility are currently evaluating the impact the guidance will have 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 counter-party. 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 months ended March 31, 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 at Level 1. Global equity securities primarily include investments in common stock that are valued based on quoted prices in active markets and are classified as Level 1. Fixed-income securities are primarily composed of U.S. government and agency securities, municipal securities, and other fixed-income securities, including corporate debt securities. U.S. government and agency securities primarily consist of U.S. Treasury securities that are classified as Level 1 because the fair value is determined by observable market prices in active markets. A market approach is generally used to estimate the fair value of fixed-income securities classified as Level 2 using evaluated pricing data such as broker quotes, for similar securities adjusted for observable differences. Significant inputs used in the valuation model generally include benchmark yield curves and issuer spreads. The external credit ratings, coupon rate, and maturity of each security are considered in the valuation model, as applicable. Assets Measured at NAV Using Practical Expedient Investments in the nuclear decommissioning trusts and the long-term disability trust that are measured at fair value using the NAV per share practical expedient have not been classified in the fair value hierarchy tables above. The fair value amounts are included in the tables above in order to reconcile to the amounts presented in the 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, 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)	3 Months Ended
	Mar. 31, 2020
Reorganizations [Abstract]
Schedule of Liabilities Subject to Compromise	The following table presents LSTC as reported in the Condensed Consolidated Balance Sheets at March 31, 2020: (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Financing debt (2) $ 22,627 $ 671 $ 23,298 Wildfire-related claims (3) 25,548 — 25,548 Trade creditors 1,200 5 1,205 Non-qualified benefit plan 20 132 152 2001 bankruptcy disputed claims (4) 238 — 238 Customer deposits & advances 78 — 78 Other 230 2 232 Total Liabilities Subject to Compromise $ 49,941 $ 810 $ 50,751 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) At March 31, 2020, PG&E Corporation and the Utility had $650 million and $21,526 million in aggregate principal amount of pre-petition indebtedness, respectively. Pre-petition financing debt includes accrued contractual interest of $1 million and $286 million for PG&E Corporation and the Utility, respectively, to the Petition Date. Financing debt also includes post-petition interest of $20 million and $815 million for PG&E Corporation and the Utility, respectively, in accordance with the terms of the Noteholder RSA. See Note 5 for details of pre-petition debt reported as LSTC. (3) See “Pre-petition Wildfire-related claims” in Note 10 for information regarding pre-petition wildfire-related claims reported as LSTC. (4) 2001 bankruptcy disputed claims includes $17 million of interest recorded at the interest rate specified by FERC in accordance with S35.19a of the Commission’s regulations. The following table presents LSTC as reported in the Consolidated Balance Sheets at December 31, 2019: (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Financing debt (2) $ 22,450 $ 666 $ 23,116 Wildfire-related claims (3) 25,548 — 25,548 Trade creditors 1,183 5 1,188 Non-qualified benefit plan 20 137 157 2001 bankruptcy disputed claims (4) 234 — 234 Customer deposits & advances 71 — 71 Other 230 2 232 Total Liabilities Subject to Compromise $ 49,736 $ 810 $ 50,546 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) At December 31, 2019, PG&E Corporation and the Utility had $650 million and $21,526 million in aggregate principal amount of pre-petition indebtedness, respectively. Pre-petition financing debt includes accrued contractual interest of $1 million and $286 million for PG&E Corporation and the Utility, respectively, to the Petition Date. Financing debt also includes post-petition interest of $15 million and $638 million for PG&E Corporation and the Utility, respectively, in accordance with the terms of the Noteholder RSA. See Note 5 for details of pre-petition debt reported as LSTC. (3) See “Pre-petition Wildfire-related claims” in Note 10 for information regarding pre-petition wildfire-related claims reported as LSTC. (4) 2001 bankruptcy disputed claims includes $14 million of interest recorded at the interest rate specified by FERC in accordance with S35.19a of the Commission’s regulations.
Schedule of Debtor Reorganization Items	Reorganization items, net for the three months ended March 31, 2020 and from the Petition Date through March 31, 2020 include the following: Three Months Ended March 31, 2020 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 3 $ — $ 3 Legal and other (2) 95 84 179 Interest income (5) (1) (6) Total reorganization items, net $ 93 $ 83 $ 176 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) Includes bridge loan facility fees. Petition Date Through March 31, 2020 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 98 $ 17 $ 115 Legal and other (2) 371 102 473 Interest income (55) (11) (66) Total reorganization items, net $ 414 $ 108 $ 522 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) Includes bridge loan facility fees. Reorganization items, net for the three months ended March 31, 2019 include the following: Three Months Ended March 31, 2019 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 97 $ 17 $ 114 Legal and other 23 1 24 Interest income (9) (2) (11) Total reorganization items, net $ 111 $ 16 $ 127 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility.

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	3 Months Ended
	Mar. 31, 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 months ended March 31, 2020 and 2019 were as follows: Pension Benefits Other Benefits Three Months Ended March 31, (in millions) 2020 2019 2020 2019 Service cost for benefits earned (1) $ 132 $ 111 $ 15 $ 14 Interest cost 178 189 16 19 Expected return on plan assets (261) (227) (34) (31) Amortization of prior service cost (1) (1) 3 4 Amortization of net actuarial loss 1 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.
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 March 31, 2020 Beginning balance $ (22) $ 17 $ (5) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $0 and $1, respectively) (1) 2 1 Amortization of net actuarial loss (net of taxes of $0 and $2, respectively) 1 (3) (2) Regulatory account transfer (net of taxes of $0 and $1, respectively) — 1 1 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 March 31, 2019 Beginning balance $ (21) $ 17 $ (4) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $0 and $1, respectively) (1) 3 2 Amortization of net actuarial loss (net of taxes of $0, and $0, respectively) 1 (1) — Regulatory account transfer (net of taxes of $0 and $1, respectively) — (2) (2) 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 March 31, (in millions) 2020 2019 Electric Revenue from contracts with customers Residential $ 1,242 $ 1,288 Commercial 1,007 953 Industrial 341 293 Agricultural 123 86 Public street and highway lighting 17 17 Other (1) (66) (309) Total revenue from contracts with customers - electric 2,664 2,328 Regulatory balancing accounts (2) 376 464 Total electric operating revenue $ 3,040 $ 2,792 Natural gas Revenue from contracts with customers Residential $ 1,066 $ 1,171 Commercial 234 240 Transportation service only 348 382 Other (1) (22) (75) Total revenue from contracts with customers - gas 1,626 1,718 Regulatory balancing accounts (2) (360) (499) Total natural gas operating revenue 1,266 1,219 Total operating revenues $ 4,306 $ 4,011 (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)	3 Months Ended
	Mar. 31, 2020
Regulated Operations [Abstract]
Long-Term Regulatory Assets	Long-term regulatory assets are comprised of the following: Balance at (in millions) March 31, 2020 December 31, 2019 Pension benefits (1) $ 1,790 $ 1,823 Environmental compliance costs 1,053 1,062 Utility retained generation (2) 216 228 Price risk management 138 124 Unamortized loss, net of gain, on reacquired debt 59 63 Catastrophic event memorandum account (3) 684 656 Wildfire expense memorandum account (4) 443 423 Fire hazard prevention memorandum account (5) 260 259 Fire risk mitigation memorandum account (6) 96 95 Wildfire mitigation plan memorandum account (7) 840 558 Deferred income taxes (8) 468 252 Other 557 523 Total long-term regulatory assets $ 6,604 $ 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 specific incremental wildfire-related liability costs the CPUC approved for tracking in June 2018. 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 March 31, 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.
Long-Term Regulatory Liabilities	Long-term regulatory liabilities are comprised of the following: Balance at (in millions) March 31, 2020 December 31, 2019 Cost of removal obligations (1) $ 6,593 $ 6,456 Recoveries in excess of AROs (2) 66 393 Public purpose programs (3) 903 817 Employee benefit plans (4) 760 750 Other 929 854 Total long-term regulatory liabilities $ 9,251 $ 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) March 31, 2020 December 31, 2019 Electric distribution $ 213 $ — Electric transmission — 9 Gas distribution and transmission 45 363 Energy procurement 881 901 Public purpose programs 288 209 Other 675 632 Total regulatory balancing accounts receivable $ 2,102 $ 2,114
Regulatory Balancing Accounts Payable	Payable Balance at (in millions) March 31, 2020 December 31, 2019 Electric distribution $ — $ 31 Electric transmission 148 119 Gas distribution and transmission 74 45 Energy procurement 585 649 Public purpose programs 565 559 Other 473 394 Total regulatory balancing accounts payable $ 1,845 $ 1,797

DEBT (Tables)

DEBT (Tables)	3 Months Ended
	Mar. 31, 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 March 31, 2020: (in millions) Termination Aggregate Limit Term Loan Borrowings Revolver Letters of Credit Outstanding Aggregate DIP Facilities December 2020 (1) $ 5,500 $ 2,000 $ — $ 774 $ 2,726
Schedule of Debt	The following table summarizes PG&E Corporation’s and the Utility’s outstanding debt subject to compromise: Balance at (in millions) Contractual Interest Rates March 31, 2020 December 31, 2019 Treatment under Plan (1) Debt Subject to Compromise (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 Other borrowings Term Loan - Stated Maturity: 2020 variable rate (4) 350 350 Repaid in cash Total PG&E Corporation Debt Subject to Compromise 650 650 Utility Senior Notes - Stated Maturity: 2020 3.50% 800 800 Exchanged for New Utility Short-Term Notes 2021 3.25% to 4.25% 550 550 Exchanged for New Utility Short-Term Notes 2022 2.45% 400 400 Exchanged for New Utility Short-Term Notes 2023 3.25% to 4.25% 1,175 1,175 Reinstated 2024 through 2028 2.95% to 4.65% 3,850 3,850 Reinstated 2034 through 2040 5.40% to 6.35% 5,700 5,700 Exchanged for New Utility Long-Term Notes 2041 through 2042 3.75% to 4.50% 1,000 1,000 Reinstated 2043 4.60% 375 375 Reinstated 2043 5.13% 500 500 Exchanged for New Utility Long-Term Notes 2044 through 2047 3.95% to 4.75% 3,175 3,175 Reinstated Total Senior notes 17,525 17,525 Pollution Control Bonds - Stated Maturity: Series 2008 F and 2010 E, due 2026 (5) 1.75% 100 100 Repaid in cash Series 2009 A-B, due 2026 (6) variable rate (7) 149 149 Exchanged for New Utility Funded Debt Exchange Notes Series 1996 C, E, F, 1997 B due 2026 (6) variable rate (8) 614 614 Exchanged for New Utility Funded Debt Exchange Notes Total pollution control bonds 863 863 Borrowings under Pre-Petition Credit Facilities Utility Revolving Credit Facilities - Stated Maturity: 2022 (9) variable rate (10) 2,888 2,888 Exchanged for New Utility Funded Debt Exchange Notes Other borrowings: Term Loan - Stated Maturity: 2019 variable rate (11) 250 250 Exchanged for New Utility Funded Debt Exchange Notes Total Borrowings under Pre-Petition Credit Facility Subject to Compromise 3,138 3,138 Total Utility Debt Subject to Compromise 21,526 21,526 Total PG&E Corporation Consolidated Debt Subject to Compromise $ 22,176 $ 22,176 (1) The treatments of debt under the Plan, described in this column relate only to the treatment of principal amounts and not pre-petition or post-petition interest. The New Utility Short-Term Notes, New Utility Long-Term Senior Notes and New Utility Funded Debt Exchange Notes are described in more detail under “Restructuring Support Agreement with the Ad Hoc Noteholder Committee” in Note 2. (2) Debt subject to compromise must be reported at the amounts expected to be allowed by the Bankruptcy Court and the carrying values will be adjusted as claims are approved. Total Debt Subject to Compromise does not include accrued contractual interest of $1 million and $286 million for PG&E Corporation and the Utility, respectively, to the Petition Date. Total Debt Subject to Compromise also does not include post-petition interest of $20 million and $815 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 March 31, 2020, the contractual LIBOR-based interest rate on loans was 2.46%. (4) At March 31, 2020, the contractual LIBOR-based interest rate on the term loan was 2.18%. (5) Pollution Control Bonds series 2008F and 2010E were reissued in June 2017. Although the stated maturity date for both series is 2026, these bonds have a mandatory redemption date of May 31, 2022. (6) Each series of these bonds is supported by a separate direct-pay letter of credit. Following the Utility’s Chapter 11 filing, investors in these bonds drew on the letter of credit facilities. The letter of credit facility supporting the Series 2009 A-B bonds matured on June 5, 2019. In December 2015, the maturity dates of the letter of credit facilities supporting the Series 1996 C, E, F, 1997 B bonds were extended to December 1, 2020. Although the stated maturity date of these bonds is 2026, each series will remain outstanding only if the Utility extends or replaces the letter of credit related to the series or otherwise obtains consent from the issuer to the continuation of the series without a credit facility. (7) At March 31, 2020, the contractual interest rate on the letter of credit facilities supporting these bonds was 6.45%. (8) At March 31, 2020, the contractual interest rate on the letter of credit facilities supporting these bonds ranged from 6.45% to 6.58%. (9) At March 31, 2020, excludes $19 million of undrawn letters of credit. (10) At March 31, 2020, the contractual LIBOR-based interest rate on the loans was 2.26%. (11) At March 31, 2020, the contractual LIBOR-based interest rate on the term loan was 1.58%.

EARNINGS PER SHARE (Tables)

EARNINGS PER SHARE (Tables)	3 Months Ended
	Mar. 31, 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 March 31, (in millions, except per share amounts) 2020 2019 Income available for common shareholders $ 371 $ 136 Weighted average common shares outstanding, basic 529 526 Add incremental shares from assumed conversions: Employee share-based compensation — 1 Chapter 11-related settlements (1) 119 — Weighted average common shares outstanding, diluted 648 527 Total income per common share, diluted $ 0.57 $ 0.25 (1) As discussed in Note 2, the financing sources for the Plan are expected to include (1) one or more PG&E Corporation common stock offerings of up to $9.0 billion and (2) the issuance of new common stock to the Fire Victim Trust. These financing sources along with the Backstop Commitment premium of 119.0 million shares of common stock (which could increase by 19,909,091 additional shares) for the Backstop Commitments will dilute current equity interests if or when such common stock is issued. At March 31, 2020, only the Backstop Commitment premium meets the requirements to be presented as incremental shares in the calculation of diluted income per common share.

DERIVATIVES (Tables)

DERIVATIVES (Tables)	3 Months Ended
	Mar. 31, 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 March 31, 2020 December 31, 2019 Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 138,102,835 131,896,159 Options 7,760,000 14,720,000 Electricity (Megawatt-hours) Forwards, Futures and Swaps 49,291,087 18,675,852 Options 4,414,400 — Congestion Revenue Rights (3) 298,648,904 308,467,999 (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 March 31, 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 $ 35 $ (6) $ 11 $ 40 Other noncurrent assets – other 133 — — 133 Current liabilities – other (31) 6 1 (24) Noncurrent liabilities – other (138) — — (138) Total commodity risk $ (1) $ — $ 12 $ 11 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 March 31, 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 $ 35 $ (6) $ 11 $ 40 Other noncurrent assets – other 133 — — 133 Current liabilities – other (31) 6 1 (24) Noncurrent liabilities – other (138) — — (138) Total commodity risk $ (1) $ — $ 12 $ 11 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)	3 Months Ended
	Mar. 31, 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 March 31, 2020 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 1,717 $ — $ — $ — $ 1,717 Nuclear decommissioning trusts Short-term investments 82 — — — 82 Global equity securities 1,792 — — — 1,792 Fixed-income securities 784 734 — — 1,518 Assets measured at NAV — — — — 17 Total nuclear decommissioning trusts (2) 2,658 734 — — 3,409 Price risk management instruments (Note 8) Electricity — 7 159 5 171 Gas — 2 — — 2 Total price risk management instruments — 9 159 5 173 Rabbi trusts Fixed-income securities — 102 — — 102 Life insurance contracts — 76 — — 76 Total rabbi trusts — 178 — — 178 Long-term disability trust Short-term investments 6 — — — 6 Assets measured at NAV — — — — 157 Total long-term disability trust 6 — — — 163 TOTAL ASSETS $ 4,381 $ 921 $ 159 $ 5 $ 5,640 Liabilities: Price risk management instruments (Note 8) Electricity $ — $ 5 $ 164 $ (7) $ 162 Gas — — — — — TOTAL LIABILITIES $ — $ 5 $ 164 $ (7) $ 162 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $498 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) March 31, 2020 Fair Value Measurement Assets Liabilities Valuation Unobservable Range (1) / Weighted-Average Price (2) Congestion revenue rights $ 141 $ 45 Market approach CRR auction prices $(45.08) - $20.20 / 0.27 Power purchase agreements $ 18 $ 119 Discounted cash flow Forward prices $9.42 - $57.42 / 32.04 (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 months ended March 31, 2020 and 2019: Price Risk Management Instruments (in millions) 2020 2019 Asset balance as of January 1 $ 5 $ 95 Net realized and unrealized gains: Included in regulatory assets and liabilities or balancing accounts (1) (10) 34 Asset balance as of March 31 $ (5) $ 129 (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 March 31, 2020 At December 31, 2019 (in millions) Carrying Amount Level 2 Fair Value Carrying Amount Level 2 Fair Value Debt (Note 5) PG&E Corporation (1) $ — $ — $ — $ — Utility (1)(2) 2,000 2,007 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 is $17.2 billion and $17.9 billion as of March 31, 2020 and December 31, 2019, respectively. 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 March 31, 2020 Amortized Total Unrealized Gains Total Unrealized Losses Total Fair Nuclear decommissioning trusts Short-term investments $ 82 $ — $ — $ 82 Global equity securities 652 1,188 (31) 1,809 Fixed-income securities 1,377 155 (14) 1,518 Total (1) $ 2,111 $ 1,343 $ (45) $ 3,409 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 $498 million and $530 million for the periods ended March 31, 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) March 31, 2020 Less than 1 year $ 26 1–5 years 397 5–10 years 408 More than 10 years 687 Total maturities of fixed-income securities $ 1,518
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 March 31, (in millions) 2020 2019 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 533 $ 346 Gross realized gains on securities 18 (34) Gross realized losses on securities (9) 19

OTHER CONTINGENCIES AND COMMI_2

OTHER CONTINGENCIES AND COMMITMENTS (Tables)	3 Months Ended
	Mar. 31, 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) March 31, 2020 December 31, 2019 Topock natural gas compressor station $ 348 $ 362 Hinkley natural gas compressor station 133 138 Former manufactured gas plant sites owned by the Utility or third parties (1) 667 568 Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites (2) 105 101 Fossil fuel-fired generation facilities and sites (3) 104 106 Total environmental remediation liability $ 1,357 $ 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)	3 Months Ended
	Mar. 31, 2020segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of operating segments (segment)	1

BANKRUPTCY FILING (Narrative) (

BANKRUPTCY FILING (Narrative) (Details)	Oct. 11, 2019USD ($)	Sep. 23, 2019USD ($)	Sep. 22, 2019USD ($)	Mar. 31, 2020USD ($)proofOfClaimstructureshares	Mar. 31, 2019USD ($)	Feb. 14, 2020USD ($)	Feb. 13, 2020USD ($)	Jan. 22, 2020USD ($)	Dec. 30, 2019USD ($)	Dec. 06, 2019USD ($)	Jan. 31, 2019USD ($)
Debt Instrument [Line Items]
TCC claims settlement, amount		$ 11,000,000,000
Subrogation claims, professional fees			$ 55,000,000
TCC RSA settlement										$ 13,500,000,000
Payment for settlement of claims										1,000,000,000
Professional fees								$ 99,000,000
Equity raise		$ 9,000,000,000
Insurance from wildfire events										2,200,000,000
Debt commitment letters, required equity funding	$ 12,000,000,000
Backstop commitment letters, tax benefits				$ 1,350,000,000
Reorganization, weighted average earning base rate				0.95
Reorganization, weighted average earnings				$ 48,000,000,000
Aggregate liability for prepetition wildfire related claims, cannot exceed amount				$ 25,500,000,000
Number of days for effective date for confirmation order				60 days
Asserted administrative expense claims, maximum				$ 250,000,000
Maximum number of structures that can be destroyed in wildfire in 2020 | structure				500
Backstop commitment letters, cash proceeds				$ 3,000,000,000
Backstop commitment premium, common stock, shares | shares				119,000,000
Backstop commitment letters, common stock, value				$ 12,000,000,000
Backstop commitment premium, common stock, market value change				$ 764,000,000
Backstop commitment premium, common stock, additional share cap (in shares) | shares				19,909,091
Backstop commitment premium, expense				$ 1,000,000,000
Professional fees reimbursement				34,000,000
Professional fees, legal, reimbursement				19,000,000
Probable of recovery				$ 18,000,000
Number of proofs of claim | proofOfClaim				100,000
Interest rate on trade payable				10.00%
Bridge Loan
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	$ 10,825,000,000
Debt instrument, term (in days)	364 days
Expected debt fees payable	$ 75,000,000
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
Pacific Gas & Electric Co
Debt Instrument [Line Items]
TCC claims settlement, amount			$ 11,000,000,000
Subrogation claims, professional fees				$ 47,500,000
Amendment, debt and equity, amount						$ 33,350,000,000	$ 30,000,000,000
Amendment, other funding, increase amount						6,000,000,000
Facility fees				14,000,000
Payments for reorganization items				117,000,000	$ 91,000,000
DIP Credit Agreement
Debt Instrument [Line Items]
Debt, face value									$ 11,900,000,000
Post-petition interest rate									2.59%
DIP Credit Agreement | Line of Credit | Secured debt
Debt Instrument [Line Items]
Amount arranged											$ 5,500,000,000
Fire Victim Trust
Debt Instrument [Line Items]
Issuance										6,750,000,000
New PG&E Corporation Debt
Debt Instrument [Line Items]
Issuance										4,750,000,000
Utility Reinstated Senior Notes
Debt Instrument [Line Items]
Debt, face value									$ 9,580,000,000
PG&E Corporation
Debt Instrument [Line Items]
Maximum amount able to be drawn										12,000,000,000
Legal fees								6,000,000
Amendment, debt and equity, amount						5,000,000,000	$ 7,000,000,000
Amendment, other funding, increase amount						$ 2,000,000,000
Facility fees				36,000,000
Payments for reorganization items				$ 57,000,000	$ 17,000,000
PG&E Corporation | New Utility Debt
Debt Instrument [Line Items]
Issuance										23,775,000,000
PG&E Corporation | New Utility Short-Term Notes
Debt Instrument [Line Items]
Issuance										1,750,000,000
Debt, face value								$ 875,000,000
Stated interest rate								3.75%
PG&E Corporation | New Debt Securities or Bank Debt
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, face value								$ 1,750,000,000
PG&E Corporation | Utility Short-Term Secured Notes Due 2025
Debt Instrument [Line Items]
Debt, face value								$ 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, face value								$ 6,200,000,000
Stated interest rate								5.00%
PG&E Corporation | Utility Long-Term Secured Notes Due 2030
Debt Instrument [Line Items]
Debt, face value								$ 3,100,000,000
Stated interest rate								4.55%
PG&E Corporation | New Utility Long-Term Notes
Debt Instrument [Line Items]
Issuance										6,200,000,000
Debt, face value								$ 3,100,000,000
Stated interest rate								4.95%
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		9,575,000,000
PG&E Corporation | Utility Funded Debt
Debt Instrument [Line Items]
Debt, face value								$ 1,949,000,000
Stated interest rate								3.15%
PG&E Corporation | New Utility Funded Debt Exchange Notes
Debt Instrument [Line Items]
Issuance										$ 3,900,000,000
Debt, face value								$ 1,949,000,000
Stated interest rate								4.50%

BANKRUPTCY FILING (Schedule of

BANKRUPTCY FILING (Schedule of Liabilities Subject to Compromise) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Reorganizations [Line Items]
Financing debt	$ 23,298	$ 23,116
Wildfire-related claims	25,548	25,548
Trade creditors	1,205	1,188
Non-qualified benefit plan	152	157
2001 bankruptcy disputed claims	238	234
Customer deposits & advances	78	71
Other	232	232
Total Liabilities Subject to Compromise	50,751	50,546
Liabilities subject to compromise, interest expense	17	14
Pacific Gas & Electric Co
Reorganizations [Line Items]
Financing debt	22,627	22,450
Wildfire-related claims	25,548	25,548
Trade creditors	1,200	1,183
Non-qualified benefit plan	20	20
2001 bankruptcy disputed claims	238	234
Customer deposits & advances	78	71
Other	230	230
Total Liabilities Subject to Compromise	49,941	49,736
Aggregate principal amount of debt subject to compromise	(21,526)	(21,526)
Accrued contractual interest subject to compromise	(286)	(286)
Post-petition interest expense	(815)	(638)
PG&E Corporation
Reorganizations [Line Items]
Financing debt	671	666
Wildfire-related claims	0	0
Trade creditors	5	5
Non-qualified benefit plan	132	137
2001 bankruptcy disputed claims	0	0
Customer deposits & advances	0	0
Other	2	2
Total Liabilities Subject to Compromise	810	810
Aggregate principal amount of debt subject to compromise	(650)	(650)
Accrued contractual interest subject to compromise	(1)	(1)
Post-petition interest expense	$ (20)	$ (15)

BANKRUPTCY FILING (Schedule o_2

BANKRUPTCY FILING (Schedule of Debtor Reorganization Items) (Details) - USD ($) $ in Millions	3 Months Ended		14 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Mar. 31, 2020
Reorganizations [Line Items]
Debtor-in-possession financing costs	$ 3	$ 114	$ 115
Legal and other	179	24	473
Interest income	(6)	(11)	(66)
Total reorganization items, net	176	127	522
PG&E Corporation
Reorganizations [Line Items]
Debtor-in-possession financing costs	0	17	17
Legal and other	84	1	102
Interest income	(1)	(2)	(11)
Total reorganization items, net	83	16	108
Utility
Reorganizations [Line Items]
Debtor-in-possession financing costs	3	97	98
Legal and other	95	23	371
Interest income	(5)	(9)	(55)
Total reorganization items, net	$ 93	$ 111	$ 414

SUMMARY OF SIGNIFICANT ACCOUN_4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Components of Net Periodic Benefit Cost) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	$ 132	$ 111
Interest cost	178	189
Expected return on plan assets	(261)	(227)
Amortization of prior service cost	(1)	(1)
Amortization of net actuarial loss	1	1
Net periodic benefit cost	49	73
Regulatory account transfer	34	10
Total	83	83
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	15	14
Interest cost	16	19
Expected return on plan assets	(34)	(31)
Amortization of prior service cost	3	4
Amortization of net actuarial loss	(5)	(1)
Net periodic benefit cost	(5)	5
Regulatory account transfer	0	0
Total	$ (5)	$ 5

SUMMARY OF SIGNIFICANT ACCOUN_5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Reclassifications Out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	$ 5,388	$ 12,903
Net current period other comprehensive gain (loss)	0	0
Ending balance	5,759	13,129
Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Net current period other comprehensive gain (loss)	0	0
Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Net current period other comprehensive gain (loss)	0	0
Accumulated Other Comprehensive Income (Loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(5)	(4)
Ending balance	(5)	(4)
Accumulated Other Comprehensive Income (Loss) | Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(22)	(21)
Ending balance	(22)	(21)
Accumulated Other Comprehensive Income (Loss) | Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	17	17
Ending balance	17	17
Amortization of prior service cost
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	1	2
Amortization of prior service cost | Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(1)	(1)
Amount attributable to tax	0	0
Amortization of prior service cost | Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	2	3
Amount attributable to tax	1	1
Amortization of net actuarial loss
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(2)	0
Amortization of net actuarial loss | Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	1	1
Amount attributable to tax	0	0
Amortization of net actuarial loss | Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(3)	(1)
Amount attributable to tax	2	0
Regulatory account transfer
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	1	(2)
Regulatory account transfer | Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	0	0
Amount attributable to tax	0	0
Regulatory account transfer | Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	1	(2)
Amount attributable to tax	$ 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
	Mar. 31, 2020	Mar. 31, 2019
Accounting Policies [Abstract]
Period for probable revenue recovery	24 months
Pacific Gas & Electric Co
Revenue from contracts with customers
Total operating revenues	$ 4,306	$ 4,011
Pacific Gas & Electric Co | Electric
Revenue from contracts with customers
Total revenue from contracts with customers	2,664	2,328
Regulatory balancing accounts	376	464
Total operating revenues	3,040	2,792
Pacific Gas & Electric Co | Electric | Residential
Revenue from contracts with customers
Total revenue from contracts with customers	1,242	1,288
Pacific Gas & Electric Co | Electric | Commercial
Revenue from contracts with customers
Total revenue from contracts with customers	1,007	953
Pacific Gas & Electric Co | Electric | Industrial
Revenue from contracts with customers
Total revenue from contracts with customers	341	293
Pacific Gas & Electric Co | Electric | Agricultural
Revenue from contracts with customers
Total revenue from contracts with customers	123	86
Pacific Gas & Electric Co | Electric | Public street and highway lighting
Revenue from contracts with customers
Total revenue from contracts with customers	17	17
Pacific Gas & Electric Co | Electric | Other
Revenue from contracts with customers
Total revenue from contracts with customers	(66)	(309)
Pacific Gas & Electric Co | Natural gas
Revenue from contracts with customers
Total revenue from contracts with customers	1,626	1,718
Regulatory balancing accounts	(360)	(499)
Total operating revenues	1,266	1,219
Pacific Gas & Electric Co | Natural gas | Residential
Revenue from contracts with customers
Total revenue from contracts with customers	1,066	1,171
Pacific Gas & Electric Co | Natural gas | Commercial
Revenue from contracts with customers
Total revenue from contracts with customers	234	240
Pacific Gas & Electric Co | Natural gas | Transportation service only
Revenue from contracts with customers
Total revenue from contracts with customers	348	382
Pacific Gas & Electric Co | Natural gas | Other
Revenue from contracts with customers
Total revenue from contracts with customers	$ (22)	$ (75)

REGULATORY ASSETS, LIABILITIE_3

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Assets) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 6,604	$ 6,066
Retained generation asset costs	1,200
Pension benefits
Regulatory Assets [Line Items]
Total long-term regulatory assets	1,790	1,823
Environmental compliance costs
Regulatory Assets [Line Items]
Total long-term regulatory assets	1,053	1,062
Utility retained generation
Regulatory Assets [Line Items]
Total long-term regulatory assets	216	228
Price risk management
Regulatory Assets [Line Items]
Total long-term regulatory assets	138	124
Unamortized loss, net of gain, on reacquired debt
Regulatory Assets [Line Items]
Total long-term regulatory assets	59	63
Catastrophic event memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	684	656
Wildfire expense memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	443	423
Fire hazard prevention memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	260	259
Fire risk mitigation memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	96	95
Wild fire mitigation plan memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	840	558
Deferred income taxes
Regulatory Assets [Line Items]
Total long-term regulatory assets	468	252
Other
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 557	$ 523

REGULATORY ASSETS, LIABILITIE_4

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Liabilities) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 9,251	$ 9,270
Cost of removal obligations
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	6,593	6,456
Recoveries in excess of AROs
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	66	393
Public purpose programs
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	903	817
Employee benefit plans
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	760	750
Other
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 929	$ 854

REGULATORY ASSETS, LIABILITIE_5

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Current Regulatory Balancing Accounts, Net) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Total regulatory balancing accounts payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	$ 1,845	$ 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	148	119
Total regulatory balancing accounts payable | Gas distribution and transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	74	45
Total regulatory balancing accounts payable | Energy procurement
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	585	649
Total regulatory balancing accounts payable | Public purpose programs
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	565	559
Total regulatory balancing accounts payable | Other
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	473	394
Total regulatory balancing accounts receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	2,102	2,114
Total regulatory balancing accounts receivable | Electric distribution
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	213	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	45	363
Total regulatory balancing accounts receivable | Energy procurement
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	881	901
Total regulatory balancing accounts receivable | Public purpose programs
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	288	209
Total regulatory balancing accounts receivable | Other
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	$ 675	$ 632

DEBT (Debtor In Possession ("DI

DEBT (Debtor In Possession ("DIP") Facilities and Financing) (Details) - USD ($)	3 Months Ended
	Mar. 31, 2020	Jan. 29, 2020	Dec. 31, 2019	Mar. 27, 2019	Feb. 01, 2019	Jan. 31, 2019
Line of Credit Facility [Line Items]
Debtor-in-possession financing, classified as current	$ 2,000,000,000		$ 1,500,000,000
Commercial paper	0
Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Debtor-in-possession financing, classified as current	2,000,000,000		$ 1,500,000,000
Commercial paper	0
Senior Secured Superpriority Debt | Line of Credit | DIP Credit Agreement
Line of Credit Facility [Line Items]
Amount arranged						$ 5,500,000,000
DIP Revolving Facility | DIP Credit Agreement | Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Aggregate Limit	5,500,000,000
Term Loan Borrowings	2,000,000,000
Revolver Borrowings	0
Letters of Credit Outstanding	774,000,000
Aggregate Availability	$ 2,726,000,000
Extension fee	0.25%
DIP Revolving Facility | Line of Credit | DIP Credit Agreement
Line of Credit Facility [Line Items]
Amount arranged					$ 3,500,000,000
DIP Revolving Facility | Line of Credit | DIP Credit Agreement | Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Debtor-in-possession financing, classified as current					1,500,000,000
Letter of Credit Subfacility | Line of Credit | DIP Credit Agreement
Line of Credit Facility [Line Items]
Amount arranged					1,500,000,000
Letter of Credit Subfacility | Line of Credit | DIP Credit Agreement | Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Amount arranged				$ 1,500,000,000
Letters of credit available					750,000,000
DIP Initial Term Loan Facility | Line of Credit | DIP Credit Agreement
Line of Credit Facility [Line Items]
Amount arranged					1,500,000,000
DIP Delayed Draw Term Loan Facility | DIP Credit Agreement | Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Amount arranged		$ 500,000,000
DIP Delayed Draw Term Loan Facility | Line of Credit | DIP Credit Agreement
Line of Credit Facility [Line Items]
Amount arranged					500,000,000
DIP Incremental Facilities | Line of Credit | DIP Credit Agreement
Line of Credit Facility [Line Items]
Amount arranged					$ 4,000,000,000

DEBT (Schedule of Long-term Deb

DEBT (Schedule of Long-term Debt) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Debt [Line Items]
Total PG&E Corporation Consolidated Debt Subject to Compromise	$ 22,176	$ 22,176
Pacific Gas & Electric Co
Debt [Line Items]
Debt	17,525	17,525
Pollution control bonds	863	863
Total Borrowings under Pre-Petition Credit Facility Subject to Compromise	3,138	3,138
Total PG&E Corporation Consolidated Debt Subject to Compromise	21,526	21,526
Accrued contractual interest subject to compromise	(286)	(286)
Post-petition interest expense	(815)	(638)
PG&E Corporation
Debt [Line Items]
Debt	650	650
Accrued contractual interest subject to compromise	(1)	(1)
Post-petition interest expense	(20)	(15)
Pre-Petition Revolver | PG&E Corporation
Debt [Line Items]
Debt	$ 300	300
Pre-Petition Revolver | PG&E Corporation | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Stated interest rate	2.46%
Pre-Petition Term Loan | PG&E Corporation
Debt [Line Items]
Debt	$ 350	350
Pre-Petition Term Loan | PG&E Corporation | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Stated interest rate	2.18%
Senior Notes Due 2020 | Pacific Gas & Electric Co
Debt [Line Items]
Stated interest rate	3.50%
Debt	$ 800	800
Senior Notes Due 2021 | Pacific Gas & Electric Co
Debt [Line Items]
Debt	$ 550	550
Senior Notes Due 2021 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Stated interest rate	3.25%
Senior Notes Due 2021 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Stated interest rate	4.25%
Senior Notes Due 2022 | Pacific Gas & Electric Co
Debt [Line Items]
Stated interest rate	2.45%
Debt	$ 400	400
Seniors Note Due 2023 | Pacific Gas & Electric Co
Debt [Line Items]
Debt	$ 1,175	1,175
Seniors Note Due 2023 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Stated interest rate	3.25%
Seniors Note Due 2023 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Stated interest rate	4.25%
Senior Notes Due 2024 Through 2028 | Pacific Gas & Electric Co
Debt [Line Items]
Debt	$ 3,850	3,850
Senior Notes Due 2024 Through 2028 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Stated interest rate	2.95%
Senior Notes Due 2024 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	5,700
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	1,000
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]
Stated interest rate	4.60%
Debt	$ 375	375
Senior Notes Due 2043 | Pacific Gas & Electric Co
Debt [Line Items]
Stated interest rate	5.13%
Debt	$ 500	500
Senior Notes Due 2024 Through 2047 | Pacific Gas & Electric Co
Debt [Line Items]
Debt	$ 3,175	3,175
Senior Notes Due 2024 Through 2047 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Stated interest rate	3.95%
Senior Notes Due 2024 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	100
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	149
Pollution Control Bonds - Series 1996 C, E, F, 1997 B due 2026 | Pacific Gas & Electric Co
Debt [Line Items]
Pollution control bonds	$ 614	614
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%
Pre-Petition Credit Facility | Pacific Gas & Electric Co
Debt [Line Items]
Borrowings under Pre-Petition Credit Facilities	$ 2,888	2,888
Undrawn letters of credit excluded	$ 19
Pre-Petition Credit Facility | Pacific Gas & Electric Co | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Stated interest rate	2.26%
Senior Notes Due 2019 | Pacific Gas & Electric Co
Debt [Line Items]
Debt	$ 250	$ 250
Senior Notes Due 2019 | Pacific Gas & Electric Co | London Interbank Offered Rate (LIBOR)
Debt [Line Items]
Stated interest rate	1.58%

EQUITY (Details)

EQUITY (Details) - USD ($) $ in Millions	Mar. 31, 2020	Mar. 20, 2020
Schedule Of Changes In Equity [Line Items]
Dividend reinstatement target, amount		$ 6,200
February 2017 Equity Distribution Agreement
Schedule Of Changes In Equity [Line Items]
Common stock, shares, issued (in shares)	0

EARNINGS PER SHARE (Details)

EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Millions	Sep. 23, 2019	Mar. 31, 2020	Mar. 31, 2019
Earnings Per Share [Abstract]
Income available for common shareholders		$ 371	$ 136
Weighted average common shares outstanding, basic (in shares)		529,000,000	526,000,000
Add incremental shares from assumed conversions:
Employee share-based compensation (in shares)		0	1,000,000
Chapter 11-realted settlements		119,000,000	0
Weighted average common shares outstanding, diluted (in shares)		648,000,000	527,000,000
Total income per common share, diluted (in dollars per share)		$ 0.57	$ 0.25
Equity raise	$ 9,000
Backstop commitment premium, common stock, shares		119,000,000
Backstop commitment premium, common stock, additional share cap (in shares)		19,909,091

DERIVATIVES (Volumes of Outstan

DERIVATIVES (Volumes of Outstanding Derivative Contracts, in Megawatt Hours Unless Otherwise Specified) (Details)	Mar. 31, 2020MWhMMBTU	Dec. 31, 2019MMBTUMWh
Forwards, Futures and Swaps | Natural Gas
Derivative [Line Items]
Contract Volume (mmbtu and mwh)	138,102,835	131,896,159
Forwards, Futures and Swaps | Electricity
Derivative [Line Items]
Contract Volume (mmbtu and mwh) | MWh	49,291,087	18,675,852
Options | Natural Gas
Derivative [Line Items]
Contract Volume (mmbtu and mwh)	7,760,000	14,720,000
Options | Electricity
Derivative [Line Items]
Contract Volume (mmbtu and mwh)	4,414,400	0
Congestion Revenue Rights | Electricity
Derivative [Line Items]
Contract Volume (mmbtu and mwh) | MWh	298,648,904	308,467,999

DERIVATIVES (Outstanding Deriva

DERIVATIVES (Outstanding Derivative Balances) (Details) - Commodity Risk - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	$ (1)	$ 5
Derivative Asset, Netting	0	0
Cash Collateral	12	6
Total Derivative Balance, Assets	11	11
Current assets – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	35	36
Derivative Asset, Netting	(6)	(6)
Cash Collateral	11	4
Total Derivative Balance, Assets	40	34
Other noncurrent assets – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	133	130
Derivative Asset, Netting	0	(6)
Cash Collateral	0	0
Total Derivative Balance, Assets	133	124
Current liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Liabilities	(31)	(31)
Derivative Liability, Netting	6	6
Cash Collateral	1	2
Total Derivative Balance, Liabilities	(24)	(23)
Noncurrent liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Liabilities	(138)	(130)
Derivative Liability, Netting	0	6
Cash Collateral	0	0
Total Derivative Balance, Liabilities	$ (138)	$ (124)

FAIR VALUE MEASUREMENTS (Assets

FAIR VALUE MEASUREMENTS (Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Assets:
Short-term investments	$ 1,717	$ 1,323
Price risk management instruments, netting	5	(8)
Price risk management instruments, assets	173	158
TOTAL ASSETS	5,640	5,523
Liabilities:
Price risk management instruments, netting	(7)	(14)
TOTAL LIABILITIES	162	147
Amount primarily related to deferred taxes on appreciation of investment value	498	530
Nuclear decommissioning trusts
Assets:
Short-term investments	82	6
Global equity securities	1,792	2,086
Fixed-income securities	1,518	1,590
TOTAL ASSETS	3,409	3,703
Rabbi trusts
Assets:
Fixed-income securities	102	100
Life insurance contracts	76	73
TOTAL ASSETS	178	173
Long-term disability trust
Assets:
Short-term investments	6	10
TOTAL ASSETS	163	166
Price Risk Derivative, Electricity
Assets:
Price risk management instruments, netting	5	(11)
Price risk management instruments, assets	171	152
Liabilities:
Price risk management instruments, netting	(7)	(13)
Price risk management instruments, liabilities	162	146
Price Risk Derivative, Gas
Assets:
Price risk management instruments, netting	0	3
Price risk management instruments, assets	2	6
Liabilities:
Price risk management instruments, netting	0	(1)
Price risk management instruments, liabilities	0	1
Level 1
Assets:
Short-term investments	1,717	1,323
Price risk management instruments, gross subject to netting	0	0
TOTAL ASSETS	4,381	4,287
Liabilities:
TOTAL LIABILITIES	0	1
Level 1 | Nuclear decommissioning trusts
Assets:
Short-term investments	82	6
Global equity securities	1,792	2,086
Fixed-income securities	784	862
TOTAL ASSETS	2,658	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 | 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	9	5
TOTAL ASSETS	921	906
Liabilities:
TOTAL LIABILITIES	5	4
Level 2 | Nuclear decommissioning trusts
Assets:
Short-term investments	0	0
Global equity securities	0	0
Fixed-income securities	734	728
TOTAL ASSETS	734	728
Level 2 | Rabbi trusts
Assets:
Fixed-income securities	102	100
Life insurance contracts	76	73
TOTAL ASSETS	178	173
Level 2 | Long-term disability trust
Assets:
Short-term investments	0	0
TOTAL ASSETS	0	0
Level 2 | Price Risk Derivative, Electricity
Assets:
Price risk management instruments, gross subject to netting	7	2
Liabilities:
Price risk management instruments, gross subject to netting	5	2
Level 2 | Price Risk Derivative, Gas
Assets:
Price risk management instruments, gross subject to netting	2	3
Liabilities:
Price risk management instruments, gross subject to netting	0	2
Level 3
Assets:
Short-term investments	0	0
Price risk management instruments, gross subject to netting	159	161
TOTAL ASSETS	159	161
Liabilities:
TOTAL LIABILITIES	164	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 | Price Risk Derivative, Electricity
Assets:
Price risk management instruments, gross subject to netting	159	161
Liabilities:
Price risk management instruments, gross subject to netting	164	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	17	21
Assets measured at NAV | Long-term disability trust
Assets:
Assets measured at NAV	$ 157	$ 156

FAIR VALUE MEASUREMENTS (Level

FAIR VALUE MEASUREMENTS (Level 3 Measurements and Sensitivity Analysis) (Details) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2020USD ($)$ / MWh	Dec. 31, 2019USD ($)$ / MWh
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets | $	$ 5,640	$ 5,523
Liabilities | $	162	147
Market approach | Congestion revenue rights
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets | $	141	140
Liabilities | $	$ 45	$ 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	(45.08)	(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	20.20	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 | $	$ 18	$ 21
Liabilities | $	$ 119	$ 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	9.42	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	57.42	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	32.04	33.62

FAIR VALUE MEASUREMENTS (Equity

FAIR VALUE MEASUREMENTS (Equity Backstop Commitments) (Details)	Mar. 31, 2020USD ($)
Fair Value Disclosures [Abstract]
Backstop commitments, fair value	$ 0
Backstop party commitment, issuance of common stock	9,000,000,000
Backstop commitment premium, fair value	$ 1,000,000,000

FAIR VALUE MEASUREMENTS (Leve_2

FAIR VALUE MEASUREMENTS (Level 3 Reconciliation) (Details) - Level 3 - Price Risk Management Instruments - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning asset balance	$ 5	$ 95
Net Realized and Unrealized Gains [Abstract]
Included in regulatory assets and liabilities or balancing accounts	(10)	34
Ending asset balance	$ (5)	$ 129

FAIR VALUE MEASUREMENTS (Carryi

FAIR VALUE MEASUREMENTS (Carrying Amount and Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Utility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value disclosure, pre-petition debt	$ 17,200	$ 17,900
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument	0	0
Carrying Amount | Utility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument	2,000	1,500
Fair Value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument	0	0
Fair Value | Utility | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument	$ 2,007	$ 1,500

FAIR VALUE MEASUREMENTS (Schedu

FAIR VALUE MEASUREMENTS (Schedule of Unrealized Gains (Losses) Related to Available-for-Sale Investments) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	$ 2,111	$ 2,011
Total Unrealized Gains	1,343	1,698
Total Unrealized Losses	(45)	(6)
Total Fair Value	3,409	3,703
Amount primarily related to deferred taxes on appreciation of investment value	498	530
Short-term investments
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	82	6
Total Unrealized Gains	0	0
Total Unrealized Losses	0	0
Total Fair Value	82	6
Global equity securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	652	500
Total Unrealized Gains	1,188	1,609
Total Unrealized Losses	(31)	(2)
Total Fair Value	1,809	2,107
Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	1,377	1,505
Total Unrealized Gains	155	89
Total Unrealized Losses	(14)	(4)
Total Fair Value	$ 1,518	$ 1,590

FAIR VALUE MEASUREMENTS (Sche_2

FAIR VALUE MEASUREMENTS (Schedule of Maturities on Debt Securities) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Debt Securities, Available-for-sale [Line Items]
Total maturities of fixed-income securities	$ 3,409	$ 3,703
Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Less than 1 year	26
1–5 years	397
5–10 years	408
More than 10 years	687
Total maturities of fixed-income securities	$ 1,518	$ 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
	Mar. 31, 2020	Mar. 31, 2019
Fair Value Disclosures [Abstract]
Proceeds from sales and maturities of nuclear decommissioning trust investments	$ 533	$ 346
Gross realized gains on securities	18	(34)
Gross realized losses on securities	$ (9)	$ 19

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES (Pre-petition Wildfire-Related Claims) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019	Dec. 06, 2019	Sep. 22, 2019
Loss Contingencies [Line Items]
Wildfire-related claims	$ 25,500
Subrogation claims, professional fees					$ 55
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Wildfire-related claims	25,500		$ 25,500
Subrogation insurance claims	11,000
Subrogation claims, professional fees	47.5
Legal fees	34	$ 47
Pacific Gas & Electric Co | Public Entity Wildfire Claims
Loss Contingencies [Line Items]
Wildfire-related claims	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_2

WILDFIRE-RELATED CONTINGENCIES (2018 Camp Fire Background) (Details) - Pacific Gas & Electric Co - 2018 Camp Fire	Nov. 08, 2018afatalitybuilding
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

WILDFIRE-RELATED CONTINGENCIE_3

WILDFIRE-RELATED CONTINGENCIES (2017 Northern California Wildfires Background) (Details) - Pacific Gas & Electric Co - 2017 Northern California wildfires a in Thousands	Oct. 30, 2017awildfirefatalitystructure
Loss Contingencies [Line Items]
Number of wildfires (wildfire)	21
Number of acres burned (acre) | a	245
Number of structures destroyed (structure) | structure	8,900
Number of fatalities (fatality) | fatality	44
Number of wildfires caused by equipment (wildfire)	20

WILDFIRE-RELATED CONTINGENCIE_4

WILDFIRE-RELATED CONTINGENCIES (Third-Party Claims, Investigations and Other Proceedings Related to the 2018 Camp Fire and 2017 Northern California Wildfires) (Details) $ in Millions	Jan. 28, 2019complaintplaintiff	Mar. 31, 2020USD ($)	Apr. 21, 2020USD ($)	Mar. 20, 2020USD ($)	Dec. 31, 2019USD ($)
Loss Contingencies [Line Items]
Wildfire-related claims		$ 25,500
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Wildfire-related claims		25,500			$ 25,500
Pacific Gas & Electric Co | 2017 Northern California wildfires and the 2018 Camp Fire
Loss Contingencies [Line Items]
Amount of claims filed		503
Fire Victim Trust
Loss Contingencies [Line Items]
Wildfire-related claims				$ 13,500
Fire Victim Trust | Subsequent event
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
FEMA | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Amount of claims filed		1,200
FEMA | 2018 Camp Fire
Loss Contingencies [Line Items]
Amount of claims filed		2,600
Cal Fire | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Amount of claims filed		133
Cal Fire | 2018 Camp Fire
Loss Contingencies [Line Items]
Amount of claims filed		110
OES | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Amount of claims filed		347
OES | 2018 Camp Fire
Loss Contingencies [Line Items]
Amount of claims filed		2,300
California Department of Transportation | 2018 Camp Fire
Loss Contingencies [Line Items]
Amount of claims filed		$ 217
Federal Agencies | Fire Victim Trust | Subsequent event
Loss Contingencies [Line Items]
Tentative agreement			1,000
Department of Justice | Fire Victim Trust | Subsequent event
Loss Contingencies [Line Items]
Tentative agreement			117
Other State Agencies | Fire Victim Trust | Subsequent event
Loss Contingencies [Line Items]
Tentative agreement			$ 89
Pending Litigation | Complaints Against PG&E Corporation and the Utility in Sacramento County Superior Court | 2018 Camp Fire
Loss Contingencies [Line Items]
Number of lawsuits filed against company (lawsuit, complaint) | complaint	100
Number of plaintiffs in lawsuit (plaintiff) | plaintiff	4,200
Pending Litigation | Complaints Against PG&E Corporation and the Utility in Sacramento County Superior Court, Classified as Class Action | 2018 Camp Fire
Loss Contingencies [Line Items]
Number of lawsuits filed against company (lawsuit, complaint) | complaint	9
Pending Litigation | Complaints Against PG&E Corporation and the Utility in San Francisco Counties Superior Courts | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Number of lawsuits filed against company (lawsuit, complaint) | complaint	750
Number of plaintiffs in lawsuit (plaintiff) | plaintiff	3,800
Pending Litigation | Lawsuits Against PG&E Corporation and the Utility in the Sonoma, Napa and San Francisco Counties Superior Courts, Classified As Class Actions | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Number of lawsuits filed against company (lawsuit, complaint) | complaint	5
Pending Litigation | Subrogation Complaints Against PG&E Corporation and the Utility in San Francisco County Superior Courts | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Number of lawsuits filed against company (lawsuit, complaint) | complaint	52
Pending Litigation | Subrogation Complaints Against PG&E Corporation and the Utility in Sacramento County Superior Court | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Number of lawsuits filed against company (lawsuit, complaint) | complaint	39

WILDFIRE-RELATED CONTINGENCIE_5

WILDFIRE-RELATED CONTINGENCIES (Plan Support Agreements with Public Entities) (Details) - Settled Litigation $ in Millions	Jun. 18, 2019USD ($)
Public Entity Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	$ 1,000
Fund to support defense or resolution of claims for each PSA	10
2017 Northern California Wildfire Public Entities [Member]
Loss Contingencies [Line Items]
Settlement reached	415
Town Of Paradise Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	270
County Of Butte Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	252
Paradise Recreation & Park District Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	47.5
County Of Yuba Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	12.5
Calaveras County Water District Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	$ 3

WILDFIRE- RELATED CONTINGENCIES

WILDFIRE- RELATED CONTINGENCIES (Restructuring Support Agreement) (Details) $ in Millions	Sep. 23, 2019USD ($)	Sep. 22, 2019USD ($)	Mar. 31, 2020USD ($)numberOfClaimHolder	Dec. 31, 2019USD ($)	Dec. 16, 2019USD ($)	Dec. 06, 2019USD ($)
Loss Contingencies [Line Items]
TCC claims settlement, amount	$ 11,000
Subrogation claims, professional fees		$ 55
Wildfire-related claims			$ 25,500
Number of claim holders | numberOfClaimHolder			8,000
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
TCC claims settlement, amount		$ 11,000
Subrogation claims, professional fees			$ 47.5
Wildfire-related claims			25,500	$ 25,500
Cash					$ 1,350
Common stock					$ 6,750
Multiplier, normalized estimated net income					14.9
Number of fully diluted shares of the reorganized, perent					20.90%
Pacific Gas & Electric Co | All Other Wildfire-related Claims
Loss Contingencies [Line Items]
Wildfire-related claims			$ 13,500			$ 13,500
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					$ 700

WILDFIRE-RELATED CONTINGENCIE_6

WILDFIRE-RELATED CONTINGENCIES (Third-Party Claims) (Details) household in Thousands, $ in Millions	Apr. 13, 2017USD ($)	Nov. 30, 2018USD ($)	May 31, 2017USD ($)	Sep. 30, 2018districtentity	Jan. 28, 2019plaintiffcomplainthousehold	May 01, 2018plaintiff	May 23, 2016contractor
Loss Contingencies [Line Items]
Number of plaintiffs in which agreements were made | plaintiff						2
Butte Fire | Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Number of vegetation management contractors (contractor) | contractor							2
Number of complaints filed (complaint) | complaint					95
Number of plaintiffs (plaintiff) | plaintiff					3,900
Number of households represented in court (household) | household					2
Number of plaintiffs, smaller public entities (plaintiff) | entity				4
Number of plaintiffs, fire districts (plaintiff) | district				3
Fire fighting costs recovery requested	$ 87
Value of claims brought against the company			$ 190
Office Of Emergency Services Claim, Proof Of Claim			$ 107
Butte Fire | Pacific Gas & Electric Co | County of Calaveras
Loss Contingencies [Line Items]
Settlement reached		$ 25

WILDFIRE-RELATED CONTINGENCIE_7

WILDFIRE-RELATED CONTINGENCIES (2018 Camp Fire and 2017 Northern California Wildfires Accounting Charge) (Details)	3 Months Ended
	Mar. 31, 2020USD ($)wild_fire
Loss Contingencies [Line Items]
Accrued charges during period	$ 0
Wildfire-related claims	$ 25,500,000,000
2017 Northern California Wildfires, other than Tubbs and 37 Fires
Loss Contingencies [Line Items]
Number of fires with probable losses (wildfire) | wild_fire	37
2017 Northern California wildfires
Loss Contingencies [Line Items]
Number of fires with probable losses (wildfire) | wild_fire	19
Subrogated Insurance Claimholders | 2018 Camp Fire, 2017 Northern California Wildfires and 2015 Butte Fire
Loss Contingencies [Line Items]
Wildfire-related claims	$ 11,000,000,000
Professional Service Reimbursement | 2018 Camp Fire, 2017 Northern California Wildfires and 2015 Butte Fire
Loss Contingencies [Line Items]
Wildfire-related claims	47,500,000
Supporting Public Entities | 2018 Camp Fire, 2017 Northern California Wildfires and 2015 Butte Fire
Loss Contingencies [Line Items]
Wildfire-related claims	1,000,000,000
Individual Claimholders | 2018 Camp Fire, 2017 Northern California Wildfires and 2015 Butte Fire
Loss Contingencies [Line Items]
Wildfire-related claims	$ 13,500,000,000

WILDFIRE-RELATED CONTINGENCIE_8

WILDFIRE-RELATED CONTINGENCIES (2019 Kincade Fire) (Details) - 2019 Kincade Fire $ in Millions	Nov. 04, 2019numberOfPeople	Mar. 31, 2020USD ($)	Oct. 23, 2019anumberOfStructureinjurycustomerstructurefacility
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

WILDFIRE-RELATED CONTINGENCIE_9

WILDFIRE-RELATED CONTINGENCIES (Loss Recoveries) (Details) - Butte Fire - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Loss Contingencies [Line Items]
Insurance settlements receivable	$ 50	$ 50
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Coverage for third party liability	922
Probable insurance recoveries	922
Cumulative reimbursements from insurance policies	60
Insurance settlements receivable	$ 50	$ 50

WILDFIRE-RELATED CONTINGENCI_10

WILDFIRE-RELATED CONTINGENCIES (Insurance) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Jul. 31, 2019
2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Liability insurance coverage		$ 1,400
Liability insurance coverage, general liability		700
Initial self-insured retention per occurrence		10
Liability insurance coverage, property damages		700
Liability insurance coverage, property damages, reinsurance		$ 200
Insurance Coverage for Wildfire Events
Loss Contingencies [Line Items]
Liability insurance coverage	$ 430
Insurance Coverage for Wildfire Events | August 1, 2019 - July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage	430
Initial self-insured retention per occurrence	10
Insurance Coverage for Wildfire Liabilities
Loss Contingencies [Line Items]
Liability insurance coverage	1,000
Initial self-insured retention per occurrence	10
Insurance Coverage for Wildfire Liabilities | August 1, 2019 - July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage	520
Insurance Coverage for Wildfire Liabilities | September 3, 2019 - September 2, 2020
Loss Contingencies [Line Items]
Liability insurance coverage	480
2018 Camp Fire
Loss Contingencies [Line Items]
Estimated insurance recoveries	1,380
Insurance settlements receivable	1,380
2017 Northern California wildfires
Loss Contingencies [Line Items]
Estimated insurance recoveries	843
Insurance settlements receivable	$ 807

WILDFIRE-RELATED CONTINGENCI_11

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%
Subsequent event
Loss Contingencies [Line Items]
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 CONTINGENCI_12

WILDFIRE-RELATED CONTINGENCIES (Wildfire-Related Derivative Litigation) (Details)	Nov. 20, 2017lawsuit
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

WILDFIRE-RELATED CONTINGENCI_13

WILDFIRE-RELATED CONTINGENCIES (Wildfire-Related Securities Class Action Litigation) (Details) - Securities Class Actions Filed in United States District Court for the Northern District of California	Feb. 22, 2019offering	Dec. 31, 2018lawsuit
Loss Contingencies [Line Items]
Number of lawsuits filed against company (lawsuit, complaint) | lawsuit		2
Number of public offerings of notes with complaints against underwriters (offering) | offering	4

WILDFIRE-RELATED CONTINGENCI_14

WILDFIRE-RELATED CONTINGENCIES (District Attorneys Offices Investigations) (Details) - Pacific Gas & Electric Co - Complaints Brought By Butte County District Attorney - Loss from Wildfires $ in Millions	Mar. 17, 2020USD ($)count
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

WILDFIRE-RELATED CONTINGENCI_15

WILDFIRE-RELATED CONTINGENCIES (Clean-up and Repair Costs) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019
Loss Contingencies [Line Items]
Capital expenditures	$ 326	$ 242
Total long-term regulatory assets	6,604		$ 6,066
Catastrophic event memorandum account
Loss Contingencies [Line Items]
Total long-term regulatory assets	684		656
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Capital expenditures	326	$ 242
Total long-term regulatory assets	6,604		$ 6,066
Pacific Gas & Electric Co | 2018 Camp Fire
Loss Contingencies [Line Items]
Service restoration and repair costs	786
Capital expenditures	327
Pacific Gas & Electric Co | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Service restoration and repair costs	365
Capital expenditures	187
Pacific Gas & Electric Co | 2019 Kincade Fire
Loss Contingencies [Line Items]
Service restoration and repair costs	60
Capital expenditures	17
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	67
Pacific Gas & Electric Co | Catastrophic event memorandum account | 2019 Kincade Fire
Loss Contingencies [Line Items]
Total long-term regulatory assets	$ 34

WILDFIRE-RELATED CONTINGENCI_16

WILDFIRE-RELATED CONTINGENCIES (Wildfire Fund) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Nov. 01, 2019	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
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
2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Wildfire-related claims			$ 105
Claimant payments		$ 74

OTHER CONTINGENCIES AND COMMI_3

OTHER CONTINGENCIES AND COMMITMENTS (Order Instituting Investigation Narrative) (Details) - USD ($) $ in Millions	Feb. 27, 2020	Mar. 31, 2020	Apr. 20, 2020	Mar. 27, 2020	Dec. 17, 2019
Loss Contingencies [Line Items]
Expenses and capital expenditures, disallowed capital, gross		$ 344
Expenses and capital expenditures, disallowed capital, net	$ 1,823	403
Expenses and capital expenditures, disallowed capital, expected charges to be recorded		59
Expenses and capital expenditures, modification, disallowed capital	198
Shareholder-funded system enhancement initiatives, modification	64
Fine payable to general fund	200
Fine payable to general fund, suspended				$ 200
Subsequent event
Loss Contingencies [Line Items]
Fine payable to general fund, suspended			$ 200
Expenses and capital expenditures, disallowed capital, approved			198
Shareholder-funded system enhancement initiatives, approved			$ 64
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		19
Expenses and capital expenditures, disallowed capital, charges recorded		71
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	$ 114				$ 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	Mar. 31, 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	Mar. 31, 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
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) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 05, 2019
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
Ex Parte Communications | Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Loss contingency liability	$ 4

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	Mar. 31, 2020	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Accrued legal liabilities	$ 117	$ 116

OTHER CONTINGENCIES AND COMMI_9

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

OTHER CONTINGENCIES AND COMM_10

OTHER CONTINGENCIES AND COMMITMENTS (Environmental Remediation Contingencies Liability) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Disclosure Commitments And Contingencies Environmental Remediation Liability Composed [Abstract]
Topock natural gas compressor station	$ 348	$ 362
Hinkley natural gas compressor station	133	138
Former manufactured gas plant sites owned by the Utility or third parties	667	568
Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites	105	101
Fossil fuel-fired generation facilities and sites	104	106
Environmental Remediation Liability	$ 1,357	$ 1,275

OTHER CONTINGENCIES AND COMM_11

OTHER CONTINGENCIES AND COMMITMENTS (Environmental Remediation Contingencies Narrative) (Details) $ in Millions	Mar. 31, 2020USD ($)
Commitments and Contingencies Disclosure [Abstract]
Amount of environmental loss accrual expected to be recovered	$ 1,029

OTHER CONTINGENCIES AND COMM_12

OTHER CONTINGENCIES AND COMMITMENTS (Natural Gas Compressor Station Sites) (Details) $ in Millions	Mar. 31, 2020USD ($)
Topock Site
Long-term Purchase Commitment [Line Items]
Total wildfire-related claims	$ 216
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	$ 129
Former Manufactured Gas Plant
Long-term Purchase Commitment [Line Items]
Total wildfire-related claims	$ 539
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	$ 78
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_13

OTHER CONTINGENCIES AND COMMITMENTS (Wildfire Insurance) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Maximum
Loss Contingencies [Line Items]
Costs for insurance coverage	$ 1,400
August 1, 2019 - September 2, 2020
Loss Contingencies [Line Items]
Costs for insurance coverage	212
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Costs for insurance coverage	50
Insurance Coverage for Property Damages
Loss Contingencies [Line Items]
Liability insurance coverage		$ 700
Insurance Coverage for Wildfire Events
Loss Contingencies [Line Items]
Liability insurance coverage	430
Insurance Coverage for Wildfire Events | August 1, 2019 - July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage	430
Initial self-insured retention per occurrence	10
Insurance Coverage For Non-Wildfire Liabilities | August 1, 2019 - July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage	1,000
Insurance Coverage for Wildfire Liabilities
Loss Contingencies [Line Items]
Liability insurance coverage	1,000
Initial self-insured retention per occurrence	10
Insurance Coverage for Wildfire Liabilities | August 1, 2019 - July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage	520
Insurance Coverage for Wildfire Liabilities | August 1, 2019 - July 31, 2020
Loss Contingencies [Line Items]
Liability insurance coverage	520
Initial self-insured retention per occurrence	10
Insurance Coverage for Wildfire Liabilities | September 3, 2019 - September 2, 2020
Loss Contingencies [Line Items]
Liability insurance coverage	480
2018 Camp Fire
Loss Contingencies [Line Items]
Estimated insurance recoveries	1,380
2017 Northern California wildfires
Loss Contingencies [Line Items]
Estimated insurance recoveries	$ 843

OTHER CONTINGENCIES AND COMM_14

OTHER CONTINGENCIES AND COMMITMENTS (Nuclear Insurance) (Details) $ in Millions	3 Months Ended
	Mar. 31, 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_15

OTHER CONTINGENCIES AND COMMITMENTS (Tax Matters) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020USD ($)
Pacific Gas & Electric Co
Disaggregation of Revenue [Line Items]
Unrecognized tax benefits, decrease resulting from settlements with taxing authorities	$ 40

OTHER CONTINGENCIES AND COMM_16

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