PG&E (PCG) 10-Q 2 May 19 2019 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2019	Apr. 25, 2019
Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Trading Symbol	PCG
Entity Registrant Name	PG&E CORP
Entity Central Index Key	0001004980
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding (in shares)		529,210,278
Pacific Gas & Electric Co
Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Trading Symbol	PCG
Entity Registrant Name	PACIFIC GAS & ELECTRIC CO
Entity Central Index Key	0000075488
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding (in shares)		264,374,809

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Operating Revenues
Total operating revenues	$ 4,011	$ 4,056
Operating Expenses
Operating and maintenance	2,087	1,604
Wildfire-related claims, net of insurance recoveries	0	(7)
Depreciation, amortization, and decommissioning	797	752
Total operating expenses	3,822	3,457
Operating Income	189	599
Interest income	22	9
Interest expense	(103)	(220)
Other income, net	71	108
Reorganization items, net	(127)	0
Income Before Income Taxes	52	496
Income tax provision (benefit)	(84)	51
Net Income	136	445
Preferred stock dividend requirement of subsidiary	0	3
Income Available for Common Shareholders	$ 136	$ 442
Weighted Average Common Shares Outstanding, Basic (in shares)	526	515
Weighted Average Common Shares Outstanding, Diluted (in shares)	527	516
Net Earnings Per Common Share, Basic (in dollars per share)	$ 0.25	$ 0.86
Net Earnings Per Common Share, Diluted (in dollars per share)	$ 0.25	$ 0.86
Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	$ 4,011	$ 4,056
Operating Expenses
Operating and maintenance	2,104	1,604
Wildfire-related claims, net of insurance recoveries	0	(7)
Depreciation, amortization, and decommissioning	797	752
Total operating expenses	3,839	3,457
Operating Income	172	599
Interest income	21	9
Interest expense	(101)	(217)
Other income, net	66	109
Reorganization items, net	(111)	0
Income Before Income Taxes	47	500
Income tax provision (benefit)	(86)	48
Net Income	133	452
Preferred stock dividend requirement of subsidiary	0	3
Income Available for Common Shareholders	133	449
Electric
Operating Revenues
Total operating revenues	2,792	2,951
Operating Expenses
Cost of goods	599	819
Electric | Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	2,792	2,951
Operating Expenses
Cost of goods	599	819
Natural gas
Operating Revenues
Total operating revenues	1,219	1,105
Operating Expenses
Cost of goods	339	289
Natural gas | Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	1,219	1,105
Operating Expenses
Cost of goods	$ 339	$ 289

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Net Income	$ 136	$ 445
Other Comprehensive Income
Pension and other post-retirement benefit plans obligations (net of taxes of $0, $0, $0, and $0, at respective dates)	0	0
Total other comprehensive income	0	0
Comprehensive Income	136	445
Preferred stock dividend requirement of subsidiary	0	3
Comprehensive Income Attributable to Common Shareholders	136	442
Pacific Gas & Electric Co
Net Income	133	452
Other Comprehensive Income
Pension and other post-retirement benefit plans obligations (net of taxes of $0, $0, $0, and $0, at respective dates)	0	0
Total other comprehensive income	0	0
Comprehensive Income	$ 133	$ 452

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
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 ($)	Mar. 31, 2019	Dec. 31, 2018
Current Assets
Cash and cash equivalents	$ 2,964,000,000	$ 1,668,000,000
Accounts receivable:
Customers (net of allowance for doubtful accounts of $56 at respective dates)	1,319,000,000	1,148,000,000
Accrued unbilled revenue	838,000,000	1,000,000,000
Regulatory balancing accounts	1,497,000,000	1,435,000,000
Other	2,695,000,000	2,686,000,000
Regulatory assets	235,000,000	233,000,000
Inventories:
Gas stored underground and fuel oil	72,000,000	111,000,000
Materials and supplies	464,000,000	443,000,000
Income taxes receivable	0	23,000,000
Other	609,000,000	448,000,000
Total current assets	10,693,000,000	9,195,000,000
Property, Plant, and Equipment
Electric	59,982,000,000	59,150,000,000
Gas	21,930,000,000	21,556,000,000
Construction work in progress	2,525,000,000	2,564,000,000
Other	20,000,000	2,000,000
Total property, plant, and equipment	84,457,000,000	83,272,000,000
Accumulated depreciation	(25,220,000,000)	(24,715,000,000)
Net property, plant, and equipment	59,237,000,000	58,557,000,000
Other Noncurrent Assets
Regulatory assets	5,151,000,000	4,964,000,000
Nuclear decommissioning trusts	2,932,000,000	2,730,000,000
Operating lease right of use asset	2,738,000,000
Income taxes receivable	69,000,000	69,000,000
Other	1,467,000,000	1,480,000,000
Total other noncurrent assets	12,357,000,000	9,243,000,000
TOTAL ASSETS	82,287,000,000	76,995,000,000
Current Liabilities
Short-term borrowings	0	3,435,000,000
Long-term debt, classified as current	0	18,559,000,000
Accounts payable:
Trade creditors	867,000,000	1,975,000,000
Regulatory balancing accounts	1,345,000,000	1,076,000,000
Other	453,000,000	464,000,000
Operating lease liabilities	539,000,000
Disputed claims and customer refunds	0	220,000,000
Interest payable	1,000,000	228,000,000
Wildfire-related claims	0	14,226,000,000
Other	1,603,000,000	1,512,000,000
Total current liabilities	4,808,000,000	41,695,000,000
Noncurrent Liabilities
Long-term debt	0	0
Debtor-in-possession financing	350,000,000	0
Regulatory liabilities	8,872,000,000	8,539,000,000
Pension and other post-retirement benefits	2,006,000,000	2,119,000,000
Asset retirement obligations	6,055,000,000	5,994,000,000
Deferred income taxes	3,273,000,000	3,281,000,000
Operating lease liabilities	2,199,000,000
Other	2,273,000,000	2,464,000,000
Total noncurrent liabilities	25,028,000,000	22,397,000,000
Liabilities Subject to Compromise	39,322,000,000	0
Shareholders' Equity
Common stock	13,000,000,000	12,910,000,000
Reinvested earnings	(114,000,000)	(250,000,000)
Accumulated other comprehensive income (loss)	(9,000,000)	(9,000,000)
Total shareholders’ equity	12,877,000,000	12,651,000,000
Noncontrolling Interest - Preferred Stock of Subsidiary	252,000,000	252,000,000
Total equity	13,129,000,000	12,903,000,000
TOTAL LIABILITIES AND EQUITY	82,287,000,000	76,995,000,000
Pacific Gas & Electric Co
Current Assets
Cash and cash equivalents	2,552,000,000	1,295,000,000
Accounts receivable:
Customers (net of allowance for doubtful accounts of $56 at respective dates)	1,319,000,000	1,148,000,000
Accrued unbilled revenue	838,000,000	1,000,000,000
Regulatory balancing accounts	1,497,000,000	1,435,000,000
Other	2,716,000,000	2,688,000,000
Regulatory assets	235,000,000	233,000,000
Inventories:
Gas stored underground and fuel oil	72,000,000	111,000,000
Materials and supplies	464,000,000	443,000,000
Income taxes receivable	0	5,000,000
Other	609,000,000	448,000,000
Total current assets	10,302,000,000	8,806,000,000
Property, Plant, and Equipment
Electric	59,982,000,000	59,150,000,000
Gas	21,930,000,000	21,556,000,000
Construction work in progress	2,525,000,000	2,564,000,000
Other	18,000,000	0
Total property, plant, and equipment	84,455,000,000	83,270,000,000
Accumulated depreciation	(25,217,000,000)	(24,713,000,000)
Net property, plant, and equipment	59,238,000,000	58,557,000,000
Other Noncurrent Assets
Regulatory assets	5,151,000,000	4,964,000,000
Nuclear decommissioning trusts	2,932,000,000	2,730,000,000
Operating lease right of use asset	2,728,000,000
Income taxes receivable	66,000,000	66,000,000
Other	1,330,000,000	1,348,000,000
Total other noncurrent assets	12,207,000,000	9,108,000,000
TOTAL ASSETS	81,747,000,000	76,471,000,000
Current Liabilities
Short-term borrowings	0	3,135,000,000
Long-term debt, classified as current	0	18,209,000,000
Accounts payable:
Trade creditors	863,000,000	1,972,000,000
Regulatory balancing accounts	1,345,000,000	1,076,000,000
Other	553,000,000	498,000,000
Operating lease liabilities	536,000,000
Disputed claims and customer refunds	0	220,000,000
Interest payable	1,000,000	227,000,000
Wildfire-related claims	14,212,000,000	14,226,000,000
Other	1,620,000,000	1,497,000,000
Total current liabilities	4,918,000,000	41,060,000,000
Noncurrent Liabilities
Long-term debt	0	0
Debtor-in-possession financing	350,000,000	0
Regulatory liabilities	8,872,000,000	8,539,000,000
Pension and other post-retirement benefits	2,006,000,000	2,026,000,000
Asset retirement obligations	6,055,000,000	5,994,000,000
Deferred income taxes	3,396,000,000	3,405,000,000
Operating lease liabilities	2,192,000,000
Other	2,323,000,000	2,492,000,000
Total noncurrent liabilities	25,194,000,000	22,456,000,000
Liabilities Subject to Compromise	38,547,000,000	0
Shareholders' Equity
Preferred stock	258,000,000	258,000,000
Common stock	1,322,000,000	1,322,000,000
Additional paid-in capital	8,550,000,000	8,550,000,000
Reinvested earnings	2,959,000,000	2,826,000,000
Accumulated other comprehensive income (loss)	(1,000,000)	(1,000,000)
Total shareholders’ equity	13,088,000,000	12,955,000,000
TOTAL LIABILITIES AND EQUITY	$ 81,747,000,000	$ 76,471,000,000

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Allowance for doubtful accounts	$ 56	$ 56
Common stock, shares authorized (in shares)	800,000,000	800,000,000
Common stock, shares outstanding (in shares)	529,210,278	520,338,710
Pacific Gas & Electric Co
Allowance for doubtful accounts	$ 56	$ 56
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		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Cash Flows from Operating Activities
Net Income	$ 136	$ 445
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	797	752
Allowance for equity funds used during construction	(25)	(32)
Deferred income taxes and tax credits, net	4	178
Reorganization items, net (Note 2)	19	0
Other	16	30
Effect of changes in operating assets and liabilities:
Accounts receivable	(31)	120
Wildfire-related insurance receivable	25	197
Inventories	18	28
Accounts payable	(180)	24
Wildfire-related claims	(14)	(118)
Income taxes receivable/payable	23	0
Other current assets and liabilities	150	(145)
Regulatory assets, liabilities, and balancing accounts, net	343	114
Liabilities subject to compromise	833	0
Other noncurrent assets and liabilities	130	(81)
Net cash provided by operating activities	2,244	1,512
Cash Flows from Investing Activities
Capital expenditures	(1,224)	(1,470)
Proceeds from sales and maturities of nuclear decommissioning trust investments	346	494
Purchases of nuclear decommissioning trust investments	(372)	(505)
Other	3	6
Net cash used in investing activities	(1,247)	(1,475)
Cash Flows from Financing Activities
Proceeds from debtor-in-possession credit facility	350	0
Debtor-in-possession credit facility debt issuance costs	(111)	0
Net issuances (repayments) of commercial paper, net of discount	0	36
Short-term debt financing	0	250
Short-term debt matured	0	(250)
Long-term debt matured or repurchased	0	(400)
Common stock issued	85	35
Other	(24)	(13)
Net cash provided by (used in) financing activities	300	(342)
Net change in cash, cash equivalents, and restricted cash	1,297	(305)
Cash, cash equivalents, and restricted cash at January 1	1,675	456	$ 456
Cash, cash equivalents, and restricted cash at March 31	2,972	151	1,675
Less: Restricted cash and restricted cash equivalents included in other current assets	(8)	(7)
Cash and cash equivalents at March 31	2,964	144	1,668
Supplemental disclosures of cash flow information
Interest, net of amounts capitalized	(10)	(268)
Supplemental disclosures of noncash operating activities
Operating lease liabilities arising from obtaining ROU assets	2,816	0
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	242	255
Pacific Gas & Electric Co
Cash Flows from Operating Activities
Net Income	133	452
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	797	752
Allowance for equity funds used during construction	(25)	(32)
Deferred income taxes and tax credits, net	2	175
Reorganization items, net (Note 2)	20	0
Other	12	(1)
Effect of changes in operating assets and liabilities:
Accounts receivable	(51)	112
Wildfire-related insurance receivable	25	197
Inventories	18	28
Accounts payable	(132)	55
Wildfire-related claims	(14)	(118)
Income taxes receivable/payable	5	0
Other current assets and liabilities	171	(131)
Regulatory assets, liabilities, and balancing accounts, net	343	114
Liabilities subject to compromise	833	0
Other noncurrent assets and liabilities	137	(87)
Net cash provided by operating activities	2,274	1,516
Cash Flows from Investing Activities
Capital expenditures	(1,224)	(1,470)
Proceeds from sales and maturities of nuclear decommissioning trust investments	346	494
Purchases of nuclear decommissioning trust investments	(372)	(505)
Other	3	6
Net cash used in investing activities	(1,247)	(1,475)
Cash Flows from Financing Activities
Proceeds from debtor-in-possession credit facility	350	0
Debtor-in-possession credit facility debt issuance costs	(95)	0
Net issuances (repayments) of commercial paper, net of discount	0	47
Short-term debt financing	0	250
Short-term debt matured	0	(250)
Long-term debt matured or repurchased	0	(400)
Other	(24)	(13)
Net cash provided by (used in) financing activities	231	(366)
Net change in cash, cash equivalents, and restricted cash	1,258	(325)
Cash, cash equivalents, and restricted cash at January 1	1,302	454	454
Cash, cash equivalents, and restricted cash at March 31	2,560	129	1,302
Less: Restricted cash and restricted cash equivalents included in other current assets	(8)	(7)
Cash and cash equivalents at March 31	2,552	122	$ 1,295
Supplemental disclosures of cash flow information
Interest, net of amounts capitalized	(8)	(259)
Supplemental disclosures of noncash operating activities
Operating lease liabilities arising from obtaining ROU assets	2,807	0
Supplemental disclosures of noncash investing and financing activities
Capital expenditures financed through accounts payable	$ 242	$ 255

ORGANIZATION AND BASIS OF PRESE

ORGANIZATION AND BASIS OF PRESENTATION	3 Months Ended
	Mar. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
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 (consisting only of normal recurring 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, 2018 in the Condensed Consolidated Balance Sheets included in this quarterly report was derived from the audited Consolidated Balance Sheets in Item 8 of the 2018 Form 10-K. This quarterly report should be read in conjunction with the 2018 Form 10-K. The preparation of financial statements in conformity with GAAP requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Some of the more significant estimates and assumptions relate to the Utility’s regulatory assets and liabilities, legal and regulatory contingencies, insurance recoveries, environmental remediation liabilities, AROs, pension and other post-retirement benefit plans obligations, and the valuation of pre-petition liabilities. 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 and results of operations 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 are facing extraordinary challenges relating to a series of catastrophic wildfires that occurred in Northern California in 2017 and 2018. 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 determined that commencing reorganization cases under Chapter 11 is 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. Pursuant to Chapter 11, PG&E Corporation and the Utility retain control of their assets and are authorized to operate their business as debtors-in-possession while being subject to the jurisdiction of the Bankruptcy Court. While operating as debtors-in-possession under Chapter 11, PG&E Corporation and the Utility may sell or otherwise dispose of or liquidate assets or settle liabilities, subject to the approval of the Bankruptcy Court or as otherwise permitted in the ordinary course of business and subject to restrictions in PG&E Corporation’s and the Utility’s DIP Credit Agreement (see Note 5 below) and applicable orders of the Bankruptcy Court, for amounts other than those reflected in the accompanying Condensed Consolidated Financial Statements. Any such actions occurring during the Chapter 11 Cases confirmed by the Bankruptcy Court could materially impact the amounts and classifications of assets and liabilities reported in PG&E Corporation’s and the Utility’s Condensed Consolidated Financial Statements. (For more information regarding the Chapter 11 Cases, see Note 2 below.)

BANKRUPTCY FILING

BANKRUPTCY FILING	3 Months Ended
	Mar. 31, 2019
Reorganizations [Abstract]
BANKRUPTCY FILING	BANKRUPTCY FILING Chapter 11 Proceedings On January 29, 2019, PG&E Corporation and the Utility filed 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), are subject to an automatic stay. Absent an order of the Bankruptcy Court providing otherwise, substantially all pre-petition liabilities will be administered under a Chapter 11 plan of reorganization to be voted upon by creditors and other stakeholders, and approved by the Bankruptcy Court. However, under the Bankruptcy Code, regulatory or criminal proceedings are generally not subject to an automatic stay, and PG&E Corporation and the Utility expect these proceedings to continue 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 2018 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 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. Debtor-In-Possession Financing See Note 5 for further discussion of the DIP Facilities, which provide up to $5.5 billion in financing. Financial Reporting in Reorganization Effective on the Petition Date, PG&E Corporation and the Utility began to apply accounting standards applicable to reorganizations, which are applicable to companies under Chapter 11 bankruptcy protection. They require the financial statements for periods subsequent to the Petition Date to distinguish transactions and events that are directly associated with the reorganization from the ongoing operations of the business. Expenses, realized gains and losses, and provisions for losses that are directly associated with reorganization proceedings must be reported separately as reorganization items, net in the Condensed Consolidated Statements of Income. In addition, the balance sheet must distinguish pre-petition LSTC of PG&E Corporation and the Utility from pre-petition liabilities that are not subject to compromise, post-petition liabilities, and liabilities of the subsidiaries of PG&E Corporation that are not debtors in the Chapter 11 Cases in the Condensed Consolidated Balance Sheets. LSTC are pre-petition obligations that are not fully secured and have at least a possibility of not being repaid at the full claim amount. Where there is uncertainty about whether a secured claim will be paid or impaired pursuant to the Chapter 11 Cases, PG&E Corporation and the Utility have classified the entire amount of the claim as LSTC. Furthermore, the realization of assets and the satisfaction of liabilities are subject to uncertainty. While operating as debtors-in-possession, certain claims against PG&E Corporation and the Utility in existence before the filing of the petitions for relief under the federal bankruptcy laws are stayed while PG&E Corporation and the Utility continue business operations as debtors in possession. These claims are reflected as LSTC in the Condensed Consolidated Balance Sheets at March 31, 2019 . Additional claims (which could be LSTC) may arise after the Petition Date resulting from rejection of executory contracts, including leases, and from the determination by the Bankruptcy Court (or agreement by parties in interest) of allowed claims for contingencies and other disputed amounts. PG&E Corporation’s Condensed Consolidated Financial Statements are presented on a consolidated basis and include the accounts of PG&E Corporation and the Utility and other subsidiaries of PG&E Corporation and the Utility that individually and in aggregate are immaterial. Such other subsidiaries did not file for bankruptcy. The Utility’s Condensed Consolidated Financial Statements are presented on a consolidated basis and include the accounts of the Utility and other subsidiaries of the Utility that individually and in aggregate are immaterial. Such other subsidiaries did not file for bankruptcy. Liabilities Subject to Compromise As a result of the commencement of the Chapter 11 Cases, the payment of pre-petition liabilities is generally subject to compromise pursuant to a plan of reorganization. Generally, actions to enforce or otherwise effect payment of pre-petition liabilities are stayed. Although payment of pre-petition claims generally is not permitted, the Bankruptcy Court granted PG&E Corporation and the Utility authority to pay certain pre-petition claims in designated categories and subject to certain terms and conditions. This relief generally was designed to preserve the value of PG&E Corporation’s and the Utility’s business and assets. Among other things, the Bankruptcy Court authorized, but did not require, PG&E Corporation and the Utility to pay certain pre-petition claims relating to employee wages and benefits, taxes, and certain vendors. As a result of the Chapter 11 Cases, the payment of pre-petition indebtedness is subject to compromise or other treatment under a plan of reorganization. The determination of how liabilities will ultimately be settled or treated cannot be made until the Bankruptcy Court confirms a Chapter 11 plan of reorganization and such plan becomes effective. Accordingly, the ultimate amount of such liabilities is not determinable at this time. GAAP requires pre-petition liabilities that are subject to compromise to be reported at the amounts expected to be allowed by the Bankruptcy Court, even if they may be settled for different amounts. The amounts currently classified as LSTC are preliminary and may be subject to future adjustments depending on Bankruptcy Court actions, further developments with respect to disputed claims, determinations of the secured status of certain claims, the values of any collateral securing such claims, rejection of executory contracts, continued reconciliation or other events. The following table presents LSTC as reported in the Condensed Consolidated Balance Sheets at March 31, 2019 : (in millions) PG&E Corporation (1) Utility PG&E Corporation Consolidated Financing debt (2) $ 650 $ 21,811 $ 22,461 Wildfire-related claims (3) — 14,212 14,212 Trade creditors 1 1,850 1,851 Non-qualified benefit plan 122 17 139 2001 bankruptcy disputed claims — 221 221 Customer deposits & advances — 272 272 Other 2 164 166 Total Liabilities Subject to Compromise $ 775 $ 38,547 $ 39,322 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) At March 31, 2019 , PG&E Corporation and the Utility had $650 million and $21,526 million in aggregate principal amount of indebtedness, respectively. Utility financing debt also includes $285 million of accrued contractual interest to the Petition Date. See Note 5 for details of pre-petition debt reported as LSTC. (3) See Note 10 for details of pre-petition wildfire-related claims reported as LSTC. Reorganization Items, Net Reorganization items, net represent amounts incurred after the Petition Date as a direct result of the Chapter 11 Cases and are comprised of professional fees and financing costs, net of interest income. Reorganization items also include adjustments to reflect the carrying value of LSTC at their estimated allowed claim amounts, as such adjustments are determined. Cash paid for reorganization items, net was $ 17 million and $ 91 million for PG&E Corporation and the Utility, respectively, during the three months ended March 31, 2019. Reorganization items, net as of March 31, 2019 include the following: Post-Petition Period Through March 31, 2019 (in millions) PG&E Corporation (1) Utility PG&E Corporation Consolidated Debtor-in-possession financing costs 17 97 114 Legal and other $ 1 $ 23 $ 24 Interest income (2 ) (9 ) (11 ) Total reorganization items, net $ 16 $ 111 $ 127 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. Contractual Interest on Debt Subject to Compromise Effective as of the Petition Date, PG&E Corporation and the Utility ceased recording interest expense on outstanding pre-petition debt. Contractual interest expense represents amounts due under the contractual terms of outstanding pre-petition debt. From the Petition Date through March 31, 2019, contractual interest expense of $166 million related to LSTC has not been recorded in the financial statements. Additionally, the portion of authorized revenues from the Petition Date through March 31, 2019 related to interest expense on pre-petition debt has been deferred as a non-current regulatory liability. Resolution of Remaining 2001 Chapter 11 Disputed Claims Various electricity suppliers filed claims in the Utility’s 2001 prior proceeding filed under Chapter 11 of the U.S. Bankruptcy Code seeking payment for energy supplied to the Utility’s customers between May 2000 and June 2001. While the FERC and judicial proceedings are pending, the Utility pursued settlements with electricity suppliers and entered into a number of settlement agreements with various electricity suppliers to resolve some of these disputed claims and to resolve the Utility’s refund claims against these electricity suppliers. Under these settlement agreements, amounts payable by the parties, in some instances, would be subject to adjustment based on the outcome of the various refund offset and interest issues being considered by the FERC. Generally, any net refunds, claim offsets, or other credits that the Utility receives from electricity suppliers either through settlement or through the conclusion of the various FERC and judicial proceedings are refunded to customers through rates in future periods. The Utility’s obligations with respect to such claims (all of which arose prior to the initiation of the Utility’s pending Chapter 11 Case on January 29, 2019), including pursuant to any prior settlements relating thereto, are expected to be determined through the proceedings of the Chapter 11 Cases.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	3 Months Ended
	Mar. 31, 2019
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 and Note 2 of the Notes to the Consolidated Financial Statements in Item 8 of the 2018 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, 2019 , 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, 2019 , 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, 2019 and 2018 were as follows: Pension Benefits Other Benefits Three Months Ended March 31, (in millions) 2019 2018 2019 2018 Service cost for benefits earned (1) $ 111 $ 128 $ 14 $ 16 Interest cost 189 172 19 17 Expected return on plan assets (227 ) (255 ) (31 ) (33 ) Amortization of prior service cost (1 ) (1 ) 4 4 Amortization of net actuarial loss 1 1 (1 ) (1 ) Net periodic benefit cost 73 45 5 3 Regulatory account transfer (2) 10 39 — — Total $ 83 $ 84 $ 5 $ 3 (1) A portion of service costs are capitalized pursuant to ASU 2017-07. (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 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) are summarized below: Pension 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: Amortization of prior service cost (net of taxes of $0 and $1, respectively) (1) (1 ) 3 2 Amortization of net actuarial loss (net of taxes of $0 and $0, respectively) (1) 1 (1 ) — Regulatory account transfer (net of taxes of $0 and $1, respectively) (1) — (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.) Pension Benefits Other Total (in millions, net of income tax) Three Months Ended March 31, 2018 Beginning balance $ (25 ) $ 17 $ (8 ) 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 ) Reclassification of stranded income tax to retained earnings (net of taxes of $0 and $0, respectively) (5 ) — (5 ) Net current period other comprehensive gain (loss) (5 ) — (5 ) Ending balance $ (30 ) $ 17 $ (13 ) (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) 2019 2018 Electric Revenue from contracts with customers Residential $ 1,288 $ 1,336 Commercial 953 1,073 Industrial 293 324 Agricultural 86 125 Public street and highway lighting 17 20 Other (1) (309 ) (201 ) Total revenue from contracts with customers - electric 2,328 2,677 Regulatory balancing accounts (2) 464 274 Total electric operating revenue $ 2,792 $ 2,951 Natural gas Revenue from contracts with customers Residential $ 1,171 $ 958 Commercial 240 196 Transportation service only 382 297 Other (1) (75 ) (52 ) Total revenue from contracts with customers - gas 1,718 1,399 Regulatory balancing accounts (2) (499 ) (294 ) Total natural gas operating revenue 1,219 1,105 Total operating revenues $ 4,011 $ 4,056 (1) This activity is primarily related to the change in unbilled revenue, partially offset by other miscellaneous revenue items. (2) These amounts represent revenues authorized to be billed or refunded to customers. Recently Adopted Accounting Standards Recognition of Lease Assets and Liabilities In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) , which amends the guidance relating to the definition of a lease, the recognition of lease assets and lease liabilities on the balance sheet, and the disclosure of key information about leasing arrangements. Under the new standard, all lessees must recognize a ROU asset, reflecting the right to use the underlying asset for the lease term, and a lease liability, reflecting the obligation to make lease payments, on the balance sheet. Operating leases were previously not recognized on the balance sheet. PG&E Corporation and the Utility adopted the ASU on January 1, 2019. PG&E Corporation and the Utility elected certain practical expedients and will carry forward historical conclusions related to (1) contracts that contain leases, (2) existing lease and easement classification, and (3) initial direct costs. After adoption of the new standard, the Corporation and Utility elected to not separate lease and non-lease components. Additionally, PG&E Corporation and the Utility have elected not to restate comparative periods upon adoption. PG&E Corporation and the Utility determine if an arrangement is a lease at inception. As most of the leases do not provide implicit discount rates, the Utility uses an estimate of its incremental secured borrowing rates based on observed market data and other information available at the lease commencement date. The ROU assets and lease liabilities include only fixed lease payments, and leases with an initial term of 12 months or less are not recorded on the balance sheet. Lease terms will only include options to extend or terminate the lease when it is reasonably certain that the Utility will exercise such options. The Utility recognizes lease expense in conformity with ratemaking. Operating leases are included in operating lease ROU assets and current and noncurrent operating lease liabilities on the Condensed Consolidated Balance Sheets. Finance leases are included in property, plant, and equipment, other current liabilities, and other noncurrent liabilities on the Condensed Consolidated Balance Sheets. Financing leases were immaterial for the three months ended March 31, 2019. Cash payments arising from operating leases were $335 million for the three months ended March 31, 2019 and are presented within operating activities on the Condensed Consolidated Statement of Cash Flows. Cash payments for the principal portion of the financing lease liability will continue to be presented within financing activities. Variable lease payments, if any, not included in the financing lease liability, if any, are presented within operating activities. On January 1, 2019, PG&E Corporation and the Utility recorded ROU assets and lease liabilities of $2.8 billion , representing the net present value of fixed lease payments and excluding any variable lease payments. This amount is presented within the supplemental disclosures of noncash activities for the three months ended, March 31, 2019. The majority of the Utility’s ROU assets and lease liabilities relate to various power purchase agreements. These power purchase agreements primarily consist of generation plants leased to meet customer demand plus applicable reserve margins, for terms between 5 years and 20 years . PG&E Corporation and the Utility have also recorded ROU assets and lease liabilities related to property and land leases. At March 31, 2019 , the Utility’s operating leases had a weighted average remaining lease term of 6.3 years and a weighted average discount rate of 6.11% . The following table shows the lease expense recognized for the fixed and variable component of the Utility’s lease obligations: (in millions) Three Months Ended March 31, 2019 Operating lease fixed cost $ 122 Operating lease variable cost 309 Total operating lease costs $ 431 The following table shows the Utility’s future expected operating lease payments: (in millions) March 31, 2019 2019 $ 686 2020 669 2021 616 2022 523 2023 195 Thereafter 672 Total lease payments 3,361 Less imputed interest (633 ) Total $ 2,728 The following table shows the Utility’s future expected obligations for power purchase and other lease commitments: (in millions) December 31, 2018 2019 $ 684 2020 677 2021 621 2022 546 2023 252 Thereafter 581 Total lease commitments $ 3,361 Accounting Standards Issued But Not Yet Adopted Fair Value Measurement In August 2018, the FASB issued ASU No. 2018-13, Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurements , which amends the existing guidance relating to the disclosure requirements for fair value measurements. The ASU will be effective for PG&E Corporation and the Utility on January 1, 2020 with early adoption permitted. PG&E Corporation and the Utility are currently evaluating the impact the guidance will have on their Condensed Consolidated Financial Statements and related disclosures. 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. This ASU will be effective for PG&E Corporation and the Utility on January 1, 2020 with early adoption permitted. 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, 2019
Regulated Operations [Abstract]
REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	REGULATORY A SSETS, LIABILITIES, AND BALANCING ACCOUNTS Regulatory Assets and Liabilities Long-Term Regulatory Assets Long-term regulatory assets are comprised of the following: Asset Balance at (in millions) March 31, 2019 December 31, 2018 Pension benefits (1) $ 1,938 $ 1,947 Environmental compliance costs 932 1,013 Utility retained generation (2) 262 274 Price risk management 65 90 Unamortized loss, net of gain, on reacquired debt (3) 237 76 Catastrophic event memorandum account (4) 865 790 Wildfire expense memorandum account (5) 111 94 Fire hazard prevention memorandum account (6) 329 263 Other 412 417 Total long-term regulatory assets $ 5,151 $ 4,964 (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 the accelerated amortization of premiums and debt issuance costs on pre-petition debt. (4) 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. (5) Includes specific incremental wildfire liability costs the CPUC approved for tracking in June 2018. Recovery of WEMA costs are subject to CPUC review and approval. (6) 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. Current Regulatory Liabilities Current regulatory liabilities are primarily comprised of the current portion of the tax reform adjustment recorded as a result of the Tax Act. Long-Term Regulatory Liabilities Long-term regulatory liabilities are comprised of the following: Liability Balance at (in millions) March 31, 2019 December 31, 2018 Cost of removal obligations (1) $ 6,134 $ 5,981 Deferred income taxes (2) 142 283 Recoveries in excess of AROs (3) 471 356 Public purpose programs (4) 758 674 Retirement Plan (5) 422 421 Other 945 824 Total long-term regulatory liabilities $ 8,872 $ 8,539 (1) Represents the cumulative differences between asset removal costs recorded and amounts collected in rates for expected asset removal costs. (2) Represents the net of amounts owed to customers for deferred taxes collected at higher rates before the Tax Act and amounts owed to the Utility for reversal of deferred taxes subject to flow-through treatment. (3) 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.) (4) 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. (5) Represents cumulative differences between incurred costs and amounts collected in rates for Post-Retirement Medical, Post-Retirement Life and Long Term Disability Plans. For more information, see Note 3 of the Notes to the Consolidated Financial Statements in Item 8 of the 2018 Form 10-K. Regulatory Balancing Accounts Current regulatory balancing accounts receivable and payable are comprised of the following: Receivable Balance at (in millions) March 31, 2019 December 31, 2018 Electric distribution $ 449 $ 160 Electric transmission 128 128 Utility generation 357 79 Gas distribution and transmission 70 462 Energy procurement 137 168 Public purpose programs 76 111 Other 280 327 Total regulatory balancing accounts receivable $ 1,497 $ 1,435 Payable Balance at (in millions) March 31, 2019 December 31, 2018 Electric transmission 146 134 Gas distribution and transmission 51 9 Energy procurement 223 59 Public purpose programs 600 587 Other 325 287 Total regulatory balancing accounts payable $ 1,345 $ 1,076 For more information, see Note 3 of the Notes to the Consolidated Financial Statements in Item 8 of the 2018 Form 10-K.

DEBT

DEBT	3 Months Ended
	Mar. 31, 2019
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. 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 February 1, 2019, the Utility borrowed $ 350 million under the DIP Revolving Facility. On April 3, 2019, following the Bankruptcy Court’s final approval of the DIP Facilities, the Utility borrowed $ 1.5 billion under the DIP Initial Term Loan Facility and repaid the $350 million outstanding under the DIP Revolving 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 15 of the Notes to the Consolidated Financial Statements in Item 8 of the 2018 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, 2019 : (in millions) Termination Date Limit Letters of Credit Outstanding Borrowings Against DIP Revolving Facility Availability DIP Facilities December 2020 (1) $ 1,500 (2) $ 131 $ 350 $ 1,019 (1) May be extended to December 2021, subject to satisfaction of certain terms and conditions, including payment of a 25 basis point extension fee. (2) On March 27, 2019, the Bankruptcy Court approved the DIP Facilities in full, but the conditions precedent to the full availability of the DIP Facilities were not satisfied until April 3, 2019. Accordingly, the amounts set forth in this table are based on the interim availability under the DIP Revolving Facility of $1.5 billion . As of March 31, 2019 , PG&E Corporation and the Utility each had no commercial paper borrowings outstanding. PG&E Corporation and the Utility do not expect to be able to access the commercial paper market for the duration of the Chapter 11 Cases. 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, 2019 December 31, 2018 Debt Subject to Compromise (1) PG&E Corporation Borrowings under Pre-Petition Credit Facilities PG&E Corporation Revolving Credit Facilities - Stated Maturity: 2022 variable rate (2) $ 300 $ 300 Other borrowings: Term Loan - Stated Maturity: 2020 variable rate (3) 350 350 Total PG&E Corporation Debt Subject to Compromise 650 650 Utility Senior Notes - Stated Maturity: 2020 3.50% 800 800 2021 3.25% to 4.25% 550 550 2022 2.45% 400 400 2023 3.25% to 4.25% 1,175 1,175 2024 through 2046 2.95% to 6.35% 14,600 14,600 Unamortized discount, net or premium and debt issuance costs — (178 ) Total Senior notes, net of premium and debt issuance costs 17,525 17,347 Pollution Control Bonds - Stated Maturity: Series 2008 F and 2010 E, due 2026 (4) 1.75% 100 100 Series 2009 A-B, due 2026 (5) variable rate (6) 149 149 Series 1996 C, E, F, 1997 B due 2026 (5) variable rate (7) 614 614 Total pollution control bonds 863 863 Borrowings under Pre-Petition Credit Facilities Utility Revolving Credit Facilities - Stated Maturity: 2022 (8) variable rate (9) 2,965 2,965 Other borrowings: Term Loan - Stated Maturity: 2019 variable rate (10) 250 250 Total Borrowings under Pre-Petition Credit Facility Subject to Compromise 3,215 3,215 Total Utility Debt Subject to Compromise 21,603 21,425 Total PG&E Corporation Consolidated Debt Subject to Compromise $ 22,253 $ 22,075 (1) LSTC must be reported at the amounts expected to be allowed by the Bankruptcy Court. The carrying value of the debt subject to compromise will be adjusted as claims are approved. As of March 31, 2019 , PG&E Corporation and the Utility wrote off $178 million of unamortized debt issuance costs and debt discount to present the debt subject to compromise at the outstanding face value. The write-offs are included within long-term regulatory assets in the Condensed Consolidated Statements of Income. See Notes 2 and 4 for further details. (2) At March 31, 2019 , the contractual LIBOR-based interest rate on loans were 3.97% . (3) At March 31, 2019 , the contractual LIBOR-based interest rate on the term loan was 3.71% . (4) 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. (5) 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 has a maturity date of 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. (6) At March 31, 2019, the contractual interest rate on the letter of credit facility supporting these bonds was 4.13% . (7) At March 31, 2019 , the contractual interest rate on the letter of credit facility supporting these bonds ranged from 4.13% to 4.47% . (8) Also includes $80 million in letters of credit. (9) At March 31, 2019 , the contractual LIBOR-based interest rate was 3.67% . (10) At March 31, 2019 , the contractual LIBOR-based interest rate was 3.09% .

EQUITY

EQUITY	3 Months Ended
	Mar. 31, 2019
Stockholders' Equity Note [Abstract]
EQUITY	EQUITY PG&E Corporation’s changes in equity for the three months ended March 31, 2019 and 2018 were as follows: (in millions, except share amounts) Common Stock Shares Common Stock Amount Reinvested Earnings Accumulated Other Comprehensive Income (Loss) Total Shareholders’ Equity Non controlling Interest - Preferred Stock of Subsidiary Total Equity Balance at December 31, 2018 520,338,710 $ 12,910 $ (250 ) $ (9 ) $ 12,651 $ 252 $ 12,903 Net income (loss) — — 136 — 136 — 136 Other comprehensive loss — — — — — — — Common stock issued, net 8,871,568 85 — — 85 — 85 Stock-based compensation amortization — 5 — — 5 — 5 Balance at March 31, 2019 529,210,278 $ 13,000 $ (114 ) $ (9 ) $ 12,877 $ 252 $ 13,129 (in millions, except share amounts) Common Stock Shares Common Stock Amount Reinvested Earnings Accumulated Other Comprehensive Income (Loss) Total Shareholders’ Equity Non controlling Interest - Preferred Stock of Subsidiary Total Equity Balance at December 31, 2017 514,775,845 $ 12,632 $ 6,596 $ (8 ) $ 19,220 $ 252 $ 19,472 Net income — — 445 — 445 — 445 Other comprehensive income — — — — — — — Common stock issued, net 1,248,112 35 — — 35 — 35 Stock-based compensation amortization — 34 — — 34 — 34 Preferred stock dividend requirement of subsidiary — — (3 ) — (3 ) — (3 ) Balance at March 31, 2018 516,023,957 $ 12,701 $ 7,038 $ (8 ) $ 19,731 $ 252 $ 19,983 The Utility’s changes in equity for the three months ended March 31, 2019 and 2018 were as follows: (in millions) Preferred Stock Common Additional Paid-in Capital Reinvested Earnings Accumulated Other Comprehensive Income (Loss) Total Shareholders’ Equity Balance at December 31, 2018 $ 258 $ 1,322 $ 8,550 $ 2,826 $ (1 ) $ 12,955 Net income (loss) — — — 133 — 133 Other comprehensive loss — — — — — — Equity contribution — — — — — — Preferred stock dividend — — — — — — Balance at March 31, 2019 $ 258 $ 1,322 $ 8,550 $ 2,959 $ (1 ) $ 13,088 (in millions) Preferred Stock Common Additional Paid-in Capital Reinvested Earnings Accumulated Other Comprehensive Income (Loss) Total Shareholders’ Equity Balance at December 31, 2017 258 1,322 8,505 9,656 6 $ 19,747 Net income — — — 452 — 452 Other comprehensive income — — — 2 (2 ) — Equity contribution — — — — — — Common stock dividend — — — — — — Preferred stock dividend — — — (3 ) — (3 ) Balance at March 31, 2018 $ 258 $ 1,322 $ 8,505 $ 10,107 $ 4 $ 20,196 There were no issuances under the PG&E Corporation February 2017 equity distribution agreement for the three months ended March 31, 2019 . PG&E Corporation issued common stock under the PG&E Corporation 401(k) plan and share-based compensation plans. During the three months ended March 31, 2019 , 8.9 million shares were issued for cash proceeds of $ 85 million under these plans. 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 the Northern California 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.” PG&E Corporation does not expect to pay any cash dividends during the Chapter 11 Cases.

EARNINGS PER SHARE

EARNINGS PER SHARE	3 Months Ended
	Mar. 31, 2019
Earnings Per Share [Abstract]
EARNINGS PER SHARE	EARNINGS PER SHARE PG&E Corporation’s basic EPS are 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) 2019 2018 Income available for common shareholders $ 136 $ 445 Preferred stock dividend requirement of subsidiary 3 3 Adjusted income available for common shareholders 133 442 Weighted average common shares outstanding, basic 526 515 Add incremental shares from assumed conversions: Employee share-based compensation 1 1 Weighted average common shares outstanding, diluted 527 516 Total earnings per common share, diluted $ 0.25 $ 0.86 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, 2019
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. 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. Volume of Derivative Activity The volumes of the Utility’s outstanding derivatives were as follows: Contract Volume at Underlying Product Instruments March 31, December 31, Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 138,016,980 177,750,349 Options 4,115,000 13,735,405 Electricity (Megawatt-hours) Forwards, Futures and Swaps 3,011,826 3,833,490 Congestion Revenue Rights (3) 335,556,726 340,783,089 (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, 2019 , the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Balance Netting Cash Collateral Total Derivative Balance Current assets – other $ 45 $ (2 ) $ 38 $ 81 Other noncurrent assets – other 165 1 — 166 Current liabilities – other (37 ) 17 3 (17 ) Noncurrent liabilities – other (49 ) (16 ) — (65 ) Total commodity risk $ 124 $ — $ 41 $ 165 At December 31, 2018 , the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Balance Netting Cash Collateral Total Derivative Balance Current assets – other $ 44 $ (1 ) $ 89 $ 132 Other noncurrent assets – other 165 — — 165 Current liabilities – other (29 ) 1 7 (21 ) Noncurrent liabilities – other (90 ) — 2 (88 ) Total commodity risk $ 90 $ — $ 98 $ 188 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, 2019
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, 2019 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 2,898 $ — $ — $ — $ 2,898 Nuclear decommissioning trusts Short-term investments 18 — — — 18 Global equity securities 1,882 — — — 1,882 Fixed-income securities 790 692 — — 1,482 Assets measured at NAV — — — — 18 Total nuclear decommissioning trusts (2) 2,690 692 — — 3,400 Price risk management instruments (Note 8) Electricity — 1 209 15 225 Gas — — — 22 22 Total price risk management instruments — 1 209 37 247 Rabbi trusts Fixed-income securities — 96 — — 96 Life insurance contracts — 69 — — 69 Total rabbi trusts — 165 — — 165 Long-term disability trust Short-term investments 8 — — — 8 Assets measured at NAV — — — — 146 Total long-term disability trust 8 — — — 154 TOTAL ASSETS $ 5,596 $ 858 $ 209 $ 37 $ 6,864 Liabilities: Price risk management instruments (Note 8) Electricity $ 1 $ 3 $ 80 $ (4 ) $ 80 Gas — 2 — — 2 TOTAL LIABILITIES $ 1 $ 5 $ 80 $ (4 ) $ 82 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $468 million , primarily related to deferred taxes on appreciation of investment value. Fair Value Measurements December 31, 2018 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 1,593 $ — $ — $ — $ 1,593 Nuclear decommissioning trusts Short-term investments 29 — — — 29 Global equity securities 1,793 — — — 1,793 Fixed-income securities 661 639 — — 1,300 Assets measured at NAV — — — — 16 Total nuclear decommissioning trusts (2) 2,483 639 — — 3,138 Price risk management instruments (Note 8) Electricity — 5 203 51 259 Gas — 1 — 37 38 Total price risk management instruments — 6 203 88 297 Rabbi trusts Fixed-income securities — 93 — — 93 Life insurance contracts — 67 — — 67 Total rabbi trusts — 160 — — 160 Long-term disability trust Short-term investments 7 — — — 7 Assets measured at NAV — — — — 155 Total long-term disability trust 7 — — — 162 TOTAL ASSETS $ 4,083 $ 805 $ 203 $ 88 $ 5,350 Liabilities: Price risk management instruments (Note 8) Electricity $ 4 $ 5 $ 108 $ (10 ) $ 107 Gas — 2 — — 2 TOTAL LIABILITIES $ 4 $ 7 $ 108 $ (10 ) $ 109 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $408 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. Transfers between levels in the fair value hierarchy are recognized as of the end of the reporting period. There were no material transfers between any levels for the three months ended March 31, 2019 and 2018 . 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. Level 3 Measurements and Sensitivity Analysis The Utility’s market and credit risk management function, which reports to PG&E Corporation’s Chief Financial Officer, is responsible for determining the fair value of the Utility’s price risk management derivatives. The Utility’s finance and risk management functions collaborate to determine the appropriate fair value methodologies and classification for each derivative. 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, 2019 Fair Value Measurement Assets Liabilities Valuation Unobservable Range (1) Congestion revenue rights $ 203 $ 60 Market approach CRR auction prices $(36.87) - 23.04 Power purchase agreements $ 6 $ 20 Discounted cash flow Forward prices $ 19.81 - 38.80 (1) Represents price per megawatt-hour. Fair Value at (in millions) December 31, 2018 Fair Value Measurement Assets Liabilities Valuation Technique Unobservable Input Range (1) Congestion revenue rights $ 203 $ 75 Market approach CRR auction prices $ (18.61) - 32.26 Power purchase agreements $ — $ 33 Discounted cash flow Forward prices $ 19.81 - 38.80 (1) Represents price per megawatt-hour. Level 3 Reconciliation The following tables present the reconciliation for Level 3 price risk management instruments for the three months ended March 31, 2019 and 2018 : Price Risk Management Instruments (in millions) 2019 2018 Asset (liability) balance as of January 1 $ 95 $ 42 Net realized and unrealized gains: Included in regulatory assets and liabilities or balancing accounts (1) 34 (2 ) Asset (liability) balance as of March 31 $ 129 $ 40 (1) The costs related to price risk management activities are fully passed through to customers in rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted. Financial Instruments PG&E Corporation and the Utility use the following methods and assumptions in estimating fair value for financial instruments: the fair values of cash, net accounts receivable, short-term borrowings, accounts payable, customer deposits, and the Utility’s variable rate pollution control bond loan agreements approximate their carrying values at March 31, 2019 and December 31, 2018 , as they are short-term in nature or have interest rates that reset daily. The carrying amount and fair value of PG&E Corporation’s and the Utility’s debt instruments were as follows (the table below excludes financial instruments with carrying values that approximate their fair values): At March 31, 2019 At December 31, 2018 (in millions) Carrying Amount Level 2 Fair Value Carrying Amount Level 2 Fair Value PG&E Corporation (1) — — $ 350 $ 350 Utility (1)(2) 350 350 17,450 14,747 (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 4. (2) The Utility drew $350 million from the DIP Revolving Facility on February 1, 2019 which was subsequently repaid on April 3, 2019 using certain of the proceeds of the DIP Initial Term Loan Facility. 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, 2019 Amortized Total Unrealized Gains Total Unrealized Losses Total Fair Nuclear decommissioning trusts Short-term investments $ 18 $ — $ — $ 18 Global equity securities 481 1,422 (3 ) 1,900 Fixed-income securities 1,432 58 (8 ) 1,482 Total (1) $ 1,931 $ 1,480 $ (11 ) $ 3,400 As of December 31, 2018 Nuclear decommissioning trusts Short-term investments $ 29 $ — $ — $ 29 Global equity securities 568 1,246 (5 ) 1,809 Fixed-income securities 1,288 30 (18 ) 1,300 Total (1) $ 1,885 $ 1,276 $ (23 ) $ 3,138 (1) Represents amounts before deducting $468 million and $408 million for the periods ended March 31, 2019 and December 31, 2018 , 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, 2019 Less than 1 year $ 31 1–5 years 534 5–10 years 337 More than 10 years 580 Total maturities of fixed-income securities $ 1,482 The following table provides a summary of activity for fixed income and equity securities: Three Months Ended March 31, (in millions) 2019 2018 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 346 $ 494 Gross realized gains on securities (34 ) 37 Gross realized losses on securities 19 (4 )

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES	3 Months Ended
	Mar. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
WILDFIRE-RELATED CONTINGENCIES	WILDFIRE-RELATED CONTINGENCIES PG&E Corporation and the Utility have significant contingencies arising from their operations, including contingencies related to wildfires. A provision for a loss contingency is recorded when it is both probable that a liability has been incurred and the amount of the liability can be reasonably estimated. PG&E Corporation and the Utility evaluate which potential liabilities are probable and the related range of reasonably estimated losses and record a charge that reflects their best estimate or the lower end of the range, if there is no better estimate. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of losses is estimable, often involves a series of complex judgments about future events. Loss contingencies are reviewed quarterly and estimates are adjusted to reflect the impact of all known information, such as negotiations, discovery, settlements and payments, rulings, advice of legal counsel, and other information and events pertaining to a particular matter. PG&E Corporation’s and the Utility’s provision for loss and expense excludes anticipated legal costs, which are expensed as incurred. PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows may be materially affected by the outcome of the following matters. Wildfire-Related Claims 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. For the three months ended March 31, 2019 and 2018 , the Utility’s Condensed Consolidated Statements of Income include estimated losses offset by insurance recoveries of $7 million for the three months ended March 31, 2018 , with no recoveries in the same period in 2019. In addition, during the three months ended March 31, 2019 , the Utility incurred $13 million and $34 million of legal and other costs related to the 2018 Camp fire and the 2017 Northern California wildfires, respectively. At March 31, 2019 and December 31, 2018 , the Utility’s Condensed Consolidated Balance Sheets include estimated liabilities in respect of total wildfire-related claims as follows: Balance at (in millions) March 31, 2019 December 31, 2018 2015 Butte fire $ 212 $ 226 2017 Northern California wildfires 3,500 3,500 2018 Camp fire 10,500 10,500 Total wildfire-related claims (1) $ 14,212 $ 14,226 (1) On the Petition Date all wildfire-related claims were classified as subject to compromise and all pending litigation was stayed. (For more information see Note 2 of the Condensed Consolidated Financial Statements.) 2018 Camp Fire Background On November 8, 2018, 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 January 4, 2019 (the “Cal Fire website”) indicated that the 2018 Camp fire consumed 153,336 acres. On the Cal Fire website, Cal Fire reported 86 fatalities and the destruction of 13,972 residences, 528 commercial structures and 4,293 other buildings resulting from the 2018 Camp fire. On February 7, 2019, the Butte County Sheriff’s Office reported that the number of fatalities resulting from the 2018 Camp fire had been reduced from 86 to 85 . There have been no subsequent updates of this information on the Cal Fire website or by the Butte County Sheriff’s Office. Although the cause of the 2018 Camp fire is still under investigation, based on the information currently known to PG&E Corporation and the Utility and reported to the CPUC and other agencies, including the facts described below, PG&E Corporation and the Utility believe it is probable that the Utility’s equipment will be determined to be an ignition point of the 2018 Camp fire. The Utility submitted two Electric Incident Reports (the “EIRs”) to the CPUC: one on November 8, 2018 and one on November 16, 2018. On December 11, 2018, the Utility publicly released a letter to the CPUC supplementing the EIRs (the “ 20 -Day Electric Incident Report”), which stated: • On the Cal Fire website, Cal Fire has identified coordinates for the 2018 Camp fire near Tower :27/222 on the Utility’s Caribou-Palermo 115 kV Transmission Line and has identified the start time of the 2018 Camp fire as 6:33 a.m. on November 8, 2018. • On November 8, 2018, at approximately 6:15 a.m., the Utility’s Caribou-Palermo 115kV Transmission Line relayed and deenergized. At approximately 6:30 a.m. that day, a Utility employee observed fire in the vicinity of Tower :27/222, and this observation was reported to 911 by Utility employees. That afternoon, the Utility observed damage on the line at Tower :27/222. Specifically, an aerial patrol identified that a suspension insulator supporting a transposition jumper had separated from an arm on Tower :27/222. • On November 14, 2018, the Utility observed a broken C-hook attached to the separated suspension insulator that had connected the suspension insulator to a tower arm, along with wear at the connection point. In addition, the Utility observed a flash mark on Tower :27/222 near where the transposition jumper was suspended and damage to the transposition jumper and suspension insulator. • In addition to the events on the Caribou-Palermo 115kV Transmission Line, on November 8, 2018, at approximately 6:45 a.m., the Utility’s Big Bend 1101 12 kV Circuit experienced an outage. On November 9, 2018, a Utility employee on patrol arrived at the location of the pole with Line Recloser (“LR”) 1704 on the Big Bend 1101 Circuit and observed that the pole and other equipment were on the ground with bullets and bullet holes at the break point of the pole and on the equipment. On November 12, 2018, a Utility employee was patrolling Concow Road north of LR 1704 when he observed wires down and damaged and downed poles at the intersection of Concow Road and Rim Road. At this location, the employee observed several snapped trees, with some on top of the downed wires. The information contained in the EIRs and the 20 -Day Electric Incident Report is factual and preliminary and does not reflect a determination of the causes of the 2018 Camp fire. These incidents remain under investigation by Cal Fire and the CPUC. With respect to the potential ignition point on the Utility’s Big Bend 1101 12 kV Circuit, although Cal Fire has identified this location as a potential ignition point, based on the condition of the site, PG&E Corporation and the Utility have not been able to determine whether the Big Bend 1101 12 kV Circuit may be a probable ignition point for the 2018 Camp fire. Neither Cal Fire nor the CPUC has publicly issued any news releases or other determinations for the 2018 Camp fire. The timing and outcome of the investigations are uncertain. PG&E Corporation and the Utility are cooperating with Cal Fire and the CPUC. Further, the CPUC’s SED is conducting investigations to assess the compliance of electric and communication companies’ facilities with applicable rules and regulations in fire-impacted areas. According to information made available by the CPUC, investigation topics include, but are not limited to, maintenance of facilities, vegetation management, and emergency preparedness and response. Various other entities, including fire departments, may also be investigating the fire. It is uncertain when the investigations will be complete and whether the SED will release any preliminary findings before its investigations are complete. 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 issued its determination on the causes of 19 of the 2017 Northern California wildfires, and alleged that all of these fires, with the exception of the Tubbs fire, involved the Utility’s equipment. Cal Fire has not publicly announced any determination of cause on the remaining wildfires. During the second quarter of 2018, Cal Fire issued news releases announcing its determination on the causes of 16 of the 2017 Northern California wildfires (the La Porte, McCourtney, Lobo, Honey, Redwood, Sulphur, Cherokee, 37, Blue, Norrbom, Adobe, Partrick, Pythian, Nuns, Pocket and Atlas fires, located in Mendocino, Lake, Butte, Sonoma, Humboldt, Nevada and Napa counties). According to the Cal Fire news releases: • the La Porte, McCourtney, Lobo and Honey fires “were caused by trees coming into contact with power lines”, and • the Redwood, Sulphur, Cherokee, 37, Blue, Norrbom, Adobe, Partrick, Pythian, Nuns, Pocket and Atlas fires “were caused by electric power and distribution lines, conductors and the failure of power poles.” Cal Fire has not yet released its investigation reports related to the McCourtney, Lobo, Sulphur, Blue, Norrbom, Adobe, Partrick, Pythian, Pocket and Atlas fires and stated in its news releases that these investigations, and the investigation related to the Honey fire, have been referred to the appropriate county District Attorney’s offices for review “due to evidence of alleged violations of state law.” (See “District Attorneys’ Offices’ Investigations” below for further information regarding the investigations by the District Attorneys’ offices related to these fires.) Also during the second quarter of 2018, Cal Fire released its investigation reports related to the Redwood, Cherokee, 37, Nuns and La Porte fires. Cal Fire did not refer these fires to District Attorney offices for investigation. On October 9, 2018, Cal Fire issued a news release announcing the results of its investigation into the Cascade fire, located in Yuba County, concluding that the Cascade fire “was started by sagging power lines coming into contact during heavy winds” and that “the power line in question was owned by Pacific Gas and Electric Company.” On October 10, 2018, Cal Fire released its investigation report related to the Cascade fire. (See “District Attorneys’ Offices’ Investigations” below for further information regarding the investigations of the Cascade fire by the Office of the District Attorney of Yuba County.) On January 24, 2019, Cal Fire issued a news release and its investigation report into the cause of the Tubbs fire. Cal Fire has determined that the Tubbs fire was caused by a private electrical system adjacent to a residential structure. Cal Fire has not publicly issued any news releases or other determinations for the Maacama, Pressley and Point wildfires. The timing and outcome of the Cal Fire investigation into these fires is uncertain. Further, the SED is conducting investigations to assess the compliance of electric and communication companies’ facilities with applicable rules and regulations in fire-impacted areas. According to information made available by the CPUC, investigation topics include, but are not limited to, maintenance of facilities, vegetation management, and emergency preparedness and response. Various other entities, including fire departments, may also be investigating certain of the fires. It is uncertain when the investigations will be complete and whether the SED will release any preliminary findings before its investigations are complete. The Utility has submitted 23 electric incident reports to the CPUC associated with the 2017 Northern California wildfires where Cal Fire or the Utility has identified a site as potentially involving the Utility’s facilities in its investigation and the property damage associated with each incident exceeded $ 50,000 . The information contained in these reports is factual and preliminary and does not reflect a determination of the causes of the fires. 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.) 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 a criminal proceeding, and it were determined that the Utility had failed to comply with applicable laws and regulations. As of January 28, 2019, PG&E Corporation and the Utility are aware of approximately 100 complaints on behalf of at least 4,200 plaintiffs related to the 2018 Camp fire, nine of which seek 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, includes claims under multiple theories of liability, including 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 assert 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 seek 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. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. As of January 28, 2019, PG&E Corporation and the Utility are aware of approximately 750 complaints on behalf of at least 3,800 plaintiffs related to the 2017 Northern California wildfires, five of which seek to be certified as class actions. These cases have been 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, includes claims under multiple theories of liability, including 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 assert 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 seek damages that include wrongful death, personal injury, property damage, evacuation costs, medical expenses, punitive damages, attorneys’ fees and other damages. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. Insurance carriers who have made payments to their insureds for property damage arising out of the 2017 Northern California wildfires have 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, insurance carriers have filed 39 similar subrogation complaints with respect to the 2018 Camp fire in the Sacramento County Superior Court and the Butte County Superior Court. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. Various government entities, including Yuba, Nevada, Lake, Mendocino, Napa and Sonoma Counties and the Cities of Santa Rosa and Clearlake, also have 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 include, 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, and PG&E Corporation and the Utility expect additional similar claims to be made by other government entities. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. On March 16, 2018, PG&E Corporation and the Utility filed a demurrer to the inverse condemnation cause of action in the 2017 Northern California wildfires litigation. On May 21, 2018, the court overruled the motion. On July 20, 2018, PG&E Corporation and the Utility filed a writ in the Court of Appeal requesting appellate review of the trial court’s decision, which was denied on September 17, 2018. On September 27, 2018, PG&E Corporation and the Utility filed a petition for review to the California Supreme Court. On November 14, 2018, the California Supreme Court denied PG&E Corporation’s and the Utility’s petition for review. PG&E Corporation and the Utility expect to be the subject of numerous additional claims in connection with the 2018 Camp fire and 2017 Northern California wildfires. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. PG&E Corporation and the Utility are continuing to review the evidence concerning the 2018 Camp fire and 2017 Northern California wildfires. PG&E Corporation and the Utility have not yet had access to all of the evidence collected by Cal Fire as part of its investigations or to many of the investigation reports prepared by Cal Fire. PG&E Corporation and the Utility and plaintiffs are in discussions with Cal Fire about access to the evidence and the remaining reports. No schedule on gaining access has been set. (See “District Attorneys’ Offices’ Investigations” below for information regarding certain investigations related to the 2018 Camp fire and 2017 Northern California wildfires.) 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 resolved through the Chapter 11 process, regulatory proceedings and any potential enforcement proceedings, all of which could take a number of years to resolve. The timing and outcome of these and other potential proceedings are uncertain. PG&E Corporation and the Utility, as part of their efforts to emerge from bankruptcy, are engaged in discussions with holders of claims related to the 2017 Northern California wildfires and the 2018 Camp Fire in an attempt to reach a global settlement of such claims. PG&E Corporation and the Utility cannot predict the outcome or timing of such discussions. Even if discussions with claimholders were successful, the consummation of such an agreement would likely be contingent on numerous uncertain conditions, including Bankruptcy Court approval and governmental action. Potential Losses in Connection with the 2018 Camp Fire and 2017 Northern California Wildfires On January 28, 2019, the California Department of Insurance issued a news release announcing an update on property losses in connection with the 2018 wildfires in Southern California (which are not in the Utility’s service territory) and the 2018 Camp fire, stating that, as of such date, “more than $ 11.4 billion in insured losses have been reported from the November 2018 fires,” of which approximately $ 8.4 billion relates to statewide claims from the 2018 Camp fire. On September 6, 2018, the California Department of Insurance issued a news release announcing that insurers have received nearly 55,000 insurance claims totaling more than $ 12.28 billion in losses, of which approximately $ 10 billion relates to statewide claims from the 2017 Northern California wildfires. The dollar amounts announced by the California Department of Insurance represent an aggregate amount of approximately $ 18.4 billion of insurance claims made as of the above dates related to the 2018 Camp fire and 2017 Northern California wildfires. PG&E Corporation and the Utility expect that additional claims have been submitted and will continue to be submitted to insurers, particularly with respect to the 2018 Camp fire. These claims reflect insured property losses only. The $ 18.4 billion of insurance claims made as of the above dates does not account for uninsured or underinsured property losses, interest, attorneys’ fees, fire suppression and clean-up costs, evacuation costs, personal injury or wrongful death damages, medical expenses or other costs, such as potential punitive damages, fines or penalties, or losses related to claims that have not manifested yet (“future claims”), each of which could be significant. The scope of all claims related to the 2018 Camp fire and 2017 Northern California wildfires is not known at this time because of the applicable statutes of limitations under California law. Potential liabilities related to the 2018 Camp fire and 2017 Northern California wildfires depend on various factors, including but not limited to the cause of each fire, contributing causes of the fires (including alternative potential origins, weather and climate related issues), the number, size and type of structures damaged or destroyed, the contents of such structures and other personal property damage, the number and types of trees damaged or destroyed, attorneys’ fees for claimants, the nature and extent of any personal injuries, including the loss of lives, the extent to which future claims arise, the amount of fire suppression and clean-up costs, other damages the Utility may be responsible for if found negligent, the amount of any penalties or fines that may be imposed by governmental entities, and the amount of any penalties, fines, or restitution orders that might result from any criminal charges brought. There are a number of unknown facts and legal considerations that may impact the amount of any potential liability. Among other things, it is uncertain at this time as to the number of wildfire-related claims that will be filed in the Chapter 11 Cases, the number of current and future claims that will be allowed by the Bankruptcy Court, how claims for punitive damages and claims by variously situated persons will be treated and whether such claims will be allowed, and the impact that historical settlement values for wildfire claims may have on the estimation of wildfire liability in the Chapter 11 Cases. If PG&E Corporation and the Utility were to be found liable for certain or all of the costs, expenses and other losses described above with respect to the 2018 Camp fire and 2017 Northern California wildfires, the amount of such liability could exceed $ 30 billion, which amount does not include potential punitive damages, fines and penalties or damages related to future claims. This estimate is based on a wide variety of data and other information available to PG&E Corporation and the Utility and their advisors, including various precedents involving similar claims, and accounts for property losses (including insured, uninsured and underinsured property losses), interest, attorneys’ fees, fire suppression and clean-up costs, evacuation costs, personal injury or wrongful death damages, medical expenses and certain other costs. This estimate is not intended to provide an upper end of the range of potential liability arising from the 2018 Camp fire and 2017 Northern California wildfires. In certain circumstances, PG&E Corporation’s and the Utility’s liability could be substantially greater than such amount. If PG&E Corporation and the Utility were to be found liable for any punitive damages or subject to fines or penalties, the amount of such punitive damages, fines and penalties could be significant. PG&E Corporation and the Utility have received significant fines and penalties in connection with past incidents. For example, in 2015, the CPUC approved a decision that imposed penalties on the Utility totaling $ 1.6 billion in connection with the natural gas explosion that occurred in the City of San Bruno, California on September 9, 2010 (the “San Bruno explosion”). These penalties represented nearly three times the underlying liability for the San Bruno explosion of approximately $ 558 million incurred for third-party claims, exclusive of shareholder derivative lawsuits and legal costs incurred. The amount of punitive damages, fines and penalties imposed on PG&E Corporation and the Utility could likewise be a significant amount in relation to the underlying liabilities with respect to the 2018 Camp fire and 2017 Northern California wildfires. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. Such proceedings are not subject to the automatic stay imposed as a result of the commencement of the Chapter 11 Cases; however, collection efforts in connection with fines or penalties arising out of such proceedings are stayed. 2018 Camp Fire and 2017 Northern California Wildfires Accounting Charge Following accounting rules, PG&E Corporation and the Utility record a liability when a loss is probable and reasonably estimable. In accordance with U.S. generally accepted accounting principles, 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 is the amount within the range that is a better estimate than any other amount 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. 2018 Camp Fire In light of the current state of the law and the information currently available to the Utility, including, among other things, the facts described in the EIRs and the 20 -Day Electric Incident Report, PG&E Corporation and the Utility have determined that it is probable they will incur a loss for claims in connection with the 2018 Camp fire, and accordingly PG&E Corporation and the Utility recorded a charge in the amount of $ 10.5 billion for the year ended December 31, 2018. This charge corresponds to the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimated losses, and is subject to change based on additional information. PG&E Corporation and the Utility currently believe that it is reasonably possible that the amount of the loss related to the 2018 Camp fire and 2017 Northern California wildfires will be greater than the amount accrued, but are unable to reasonably estimate the additional loss and the upper end of the range because there are a number of unknown facts and legal considerations that may impact the amount of any potential liability, including the total scope and nature of claims that may be asserted against PG&E Corporation and the Utility. PG&E Corporation and the Utility intend to continue to review the available information and other information as it becomes available, including evidence in Cal Fire’s possession, evidence from or held by other parties, claims that have not yet been submitted, and additional information about the nature and extent of personal and business property damage and losses, the nature, number and severity of personal injuries, and information made available through the discovery process. The process for estimating losses associated with claims requires management to exercise significant judgment based on a number of assumptions and subjective factors, including but not limited to factors identified above and estimates based on currently available information and prior experience with wildfires. As more information becomes available, management estimates and assumptions regarding the financial impact of the 2018 Camp fire may change, which could result in material increases to the loss accrued. The $ 10.5 billion charge does not include any amounts for potential penalties or fines that may be imposed by governmental entities on PG&E Corporation or the Utility, or punitive damages, if any, or any losses related to future claims for damages that have not manifested yet, each of which could be significant. 2017 Northern California Wildfires In light of the current state of the law on inverse condemnation and the information currently available to the Utility, including, among other things, the Cal Fire determinations of cause as stated in Cal Fire’s press releases and their released reports, PG&E Corporation and the Utility have determined that it is probable they will incur a loss for claims in connection with 17 of the 2017 Northern California wildfires referred to as the La Porte, McCourtney, Lobo, Honey, Redwood, Sulphur, Cherokee, Blue, Pocket, Atlas, Cascade, Point and Sonoma/Napa merged fires (which include the Nuns, Norrbom, Adobe, Partrick and Pythian fires). Accordingly, PG&E Corporation and the Utility recorded a charge in the amount of $ 2.5 billion during the quarter ended June 30, 2018 and a charge in the amount of $ 1.0 billion during the quarter ended December 31, 2018, for a total charge in the amount of $ 3.5 billion for the year ended December 31, 2018. This charge corresponds to the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimated losses and is subject to change based on additional information. PG&E Corporation and the Utility currently believe that it is reasonably possible that the amount of the loss related to the 2017 Northern California wildfires and the 2018 Camp fire will be greater than the amount accrued, but are unable to reasonably estimate the additional loss and the upper end of the range because there are a number of unknown facts and legal considerations that may impact the amount of any potential liability, including the total scope and nature of claims that ma

OTHER CONTINGENCIES AND COMMITM

OTHER CONTINGENCIES AND COMMITMENTS	3 Months Ended
	Mar. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
OTHER CONTINGENCIES AND COMMITMENTS	WILDFIRE-RELATED CONTINGENCIES PG&E Corporation and the Utility have significant contingencies arising from their operations, including contingencies related to wildfires. A provision for a loss contingency is recorded when it is both probable that a liability has been incurred and the amount of the liability can be reasonably estimated. PG&E Corporation and the Utility evaluate which potential liabilities are probable and the related range of reasonably estimated losses and record a charge that reflects their best estimate or the lower end of the range, if there is no better estimate. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of losses is estimable, often involves a series of complex judgments about future events. Loss contingencies are reviewed quarterly and estimates are adjusted to reflect the impact of all known information, such as negotiations, discovery, settlements and payments, rulings, advice of legal counsel, and other information and events pertaining to a particular matter. PG&E Corporation’s and the Utility’s provision for loss and expense excludes anticipated legal costs, which are expensed as incurred. PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity, and cash flows may be materially affected by the outcome of the following matters. Wildfire-Related Claims 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. For the three months ended March 31, 2019 and 2018 , the Utility’s Condensed Consolidated Statements of Income include estimated losses offset by insurance recoveries of $7 million for the three months ended March 31, 2018 , with no recoveries in the same period in 2019. In addition, during the three months ended March 31, 2019 , the Utility incurred $13 million and $34 million of legal and other costs related to the 2018 Camp fire and the 2017 Northern California wildfires, respectively. At March 31, 2019 and December 31, 2018 , the Utility’s Condensed Consolidated Balance Sheets include estimated liabilities in respect of total wildfire-related claims as follows: Balance at (in millions) March 31, 2019 December 31, 2018 2015 Butte fire $ 212 $ 226 2017 Northern California wildfires 3,500 3,500 2018 Camp fire 10,500 10,500 Total wildfire-related claims (1) $ 14,212 $ 14,226 (1) On the Petition Date all wildfire-related claims were classified as subject to compromise and all pending litigation was stayed. (For more information see Note 2 of the Condensed Consolidated Financial Statements.) 2018 Camp Fire Background On November 8, 2018, 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 January 4, 2019 (the “Cal Fire website”) indicated that the 2018 Camp fire consumed 153,336 acres. On the Cal Fire website, Cal Fire reported 86 fatalities and the destruction of 13,972 residences, 528 commercial structures and 4,293 other buildings resulting from the 2018 Camp fire. On February 7, 2019, the Butte County Sheriff’s Office reported that the number of fatalities resulting from the 2018 Camp fire had been reduced from 86 to 85 . There have been no subsequent updates of this information on the Cal Fire website or by the Butte County Sheriff’s Office. Although the cause of the 2018 Camp fire is still under investigation, based on the information currently known to PG&E Corporation and the Utility and reported to the CPUC and other agencies, including the facts described below, PG&E Corporation and the Utility believe it is probable that the Utility’s equipment will be determined to be an ignition point of the 2018 Camp fire. The Utility submitted two Electric Incident Reports (the “EIRs”) to the CPUC: one on November 8, 2018 and one on November 16, 2018. On December 11, 2018, the Utility publicly released a letter to the CPUC supplementing the EIRs (the “ 20 -Day Electric Incident Report”), which stated: • On the Cal Fire website, Cal Fire has identified coordinates for the 2018 Camp fire near Tower :27/222 on the Utility’s Caribou-Palermo 115 kV Transmission Line and has identified the start time of the 2018 Camp fire as 6:33 a.m. on November 8, 2018. • On November 8, 2018, at approximately 6:15 a.m., the Utility’s Caribou-Palermo 115kV Transmission Line relayed and deenergized. At approximately 6:30 a.m. that day, a Utility employee observed fire in the vicinity of Tower :27/222, and this observation was reported to 911 by Utility employees. That afternoon, the Utility observed damage on the line at Tower :27/222. Specifically, an aerial patrol identified that a suspension insulator supporting a transposition jumper had separated from an arm on Tower :27/222. • On November 14, 2018, the Utility observed a broken C-hook attached to the separated suspension insulator that had connected the suspension insulator to a tower arm, along with wear at the connection point. In addition, the Utility observed a flash mark on Tower :27/222 near where the transposition jumper was suspended and damage to the transposition jumper and suspension insulator. • In addition to the events on the Caribou-Palermo 115kV Transmission Line, on November 8, 2018, at approximately 6:45 a.m., the Utility’s Big Bend 1101 12 kV Circuit experienced an outage. On November 9, 2018, a Utility employee on patrol arrived at the location of the pole with Line Recloser (“LR”) 1704 on the Big Bend 1101 Circuit and observed that the pole and other equipment were on the ground with bullets and bullet holes at the break point of the pole and on the equipment. On November 12, 2018, a Utility employee was patrolling Concow Road north of LR 1704 when he observed wires down and damaged and downed poles at the intersection of Concow Road and Rim Road. At this location, the employee observed several snapped trees, with some on top of the downed wires. The information contained in the EIRs and the 20 -Day Electric Incident Report is factual and preliminary and does not reflect a determination of the causes of the 2018 Camp fire. These incidents remain under investigation by Cal Fire and the CPUC. With respect to the potential ignition point on the Utility’s Big Bend 1101 12 kV Circuit, although Cal Fire has identified this location as a potential ignition point, based on the condition of the site, PG&E Corporation and the Utility have not been able to determine whether the Big Bend 1101 12 kV Circuit may be a probable ignition point for the 2018 Camp fire. Neither Cal Fire nor the CPUC has publicly issued any news releases or other determinations for the 2018 Camp fire. The timing and outcome of the investigations are uncertain. PG&E Corporation and the Utility are cooperating with Cal Fire and the CPUC. Further, the CPUC’s SED is conducting investigations to assess the compliance of electric and communication companies’ facilities with applicable rules and regulations in fire-impacted areas. According to information made available by the CPUC, investigation topics include, but are not limited to, maintenance of facilities, vegetation management, and emergency preparedness and response. Various other entities, including fire departments, may also be investigating the fire. It is uncertain when the investigations will be complete and whether the SED will release any preliminary findings before its investigations are complete. 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 issued its determination on the causes of 19 of the 2017 Northern California wildfires, and alleged that all of these fires, with the exception of the Tubbs fire, involved the Utility’s equipment. Cal Fire has not publicly announced any determination of cause on the remaining wildfires. During the second quarter of 2018, Cal Fire issued news releases announcing its determination on the causes of 16 of the 2017 Northern California wildfires (the La Porte, McCourtney, Lobo, Honey, Redwood, Sulphur, Cherokee, 37, Blue, Norrbom, Adobe, Partrick, Pythian, Nuns, Pocket and Atlas fires, located in Mendocino, Lake, Butte, Sonoma, Humboldt, Nevada and Napa counties). According to the Cal Fire news releases: • the La Porte, McCourtney, Lobo and Honey fires “were caused by trees coming into contact with power lines”, and • the Redwood, Sulphur, Cherokee, 37, Blue, Norrbom, Adobe, Partrick, Pythian, Nuns, Pocket and Atlas fires “were caused by electric power and distribution lines, conductors and the failure of power poles.” Cal Fire has not yet released its investigation reports related to the McCourtney, Lobo, Sulphur, Blue, Norrbom, Adobe, Partrick, Pythian, Pocket and Atlas fires and stated in its news releases that these investigations, and the investigation related to the Honey fire, have been referred to the appropriate county District Attorney’s offices for review “due to evidence of alleged violations of state law.” (See “District Attorneys’ Offices’ Investigations” below for further information regarding the investigations by the District Attorneys’ offices related to these fires.) Also during the second quarter of 2018, Cal Fire released its investigation reports related to the Redwood, Cherokee, 37, Nuns and La Porte fires. Cal Fire did not refer these fires to District Attorney offices for investigation. On October 9, 2018, Cal Fire issued a news release announcing the results of its investigation into the Cascade fire, located in Yuba County, concluding that the Cascade fire “was started by sagging power lines coming into contact during heavy winds” and that “the power line in question was owned by Pacific Gas and Electric Company.” On October 10, 2018, Cal Fire released its investigation report related to the Cascade fire. (See “District Attorneys’ Offices’ Investigations” below for further information regarding the investigations of the Cascade fire by the Office of the District Attorney of Yuba County.) On January 24, 2019, Cal Fire issued a news release and its investigation report into the cause of the Tubbs fire. Cal Fire has determined that the Tubbs fire was caused by a private electrical system adjacent to a residential structure. Cal Fire has not publicly issued any news releases or other determinations for the Maacama, Pressley and Point wildfires. The timing and outcome of the Cal Fire investigation into these fires is uncertain. Further, the SED is conducting investigations to assess the compliance of electric and communication companies’ facilities with applicable rules and regulations in fire-impacted areas. According to information made available by the CPUC, investigation topics include, but are not limited to, maintenance of facilities, vegetation management, and emergency preparedness and response. Various other entities, including fire departments, may also be investigating certain of the fires. It is uncertain when the investigations will be complete and whether the SED will release any preliminary findings before its investigations are complete. The Utility has submitted 23 electric incident reports to the CPUC associated with the 2017 Northern California wildfires where Cal Fire or the Utility has identified a site as potentially involving the Utility’s facilities in its investigation and the property damage associated with each incident exceeded $ 50,000 . The information contained in these reports is factual and preliminary and does not reflect a determination of the causes of the fires. 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.) 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 a criminal proceeding, and it were determined that the Utility had failed to comply with applicable laws and regulations. As of January 28, 2019, PG&E Corporation and the Utility are aware of approximately 100 complaints on behalf of at least 4,200 plaintiffs related to the 2018 Camp fire, nine of which seek 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, includes claims under multiple theories of liability, including 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 assert 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 seek 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. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. As of January 28, 2019, PG&E Corporation and the Utility are aware of approximately 750 complaints on behalf of at least 3,800 plaintiffs related to the 2017 Northern California wildfires, five of which seek to be certified as class actions. These cases have been 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, includes claims under multiple theories of liability, including 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 assert 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 seek damages that include wrongful death, personal injury, property damage, evacuation costs, medical expenses, punitive damages, attorneys’ fees and other damages. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. Insurance carriers who have made payments to their insureds for property damage arising out of the 2017 Northern California wildfires have 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, insurance carriers have filed 39 similar subrogation complaints with respect to the 2018 Camp fire in the Sacramento County Superior Court and the Butte County Superior Court. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. Various government entities, including Yuba, Nevada, Lake, Mendocino, Napa and Sonoma Counties and the Cities of Santa Rosa and Clearlake, also have 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 include, 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, and PG&E Corporation and the Utility expect additional similar claims to be made by other government entities. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. On March 16, 2018, PG&E Corporation and the Utility filed a demurrer to the inverse condemnation cause of action in the 2017 Northern California wildfires litigation. On May 21, 2018, the court overruled the motion. On July 20, 2018, PG&E Corporation and the Utility filed a writ in the Court of Appeal requesting appellate review of the trial court’s decision, which was denied on September 17, 2018. On September 27, 2018, PG&E Corporation and the Utility filed a petition for review to the California Supreme Court. On November 14, 2018, the California Supreme Court denied PG&E Corporation’s and the Utility’s petition for review. PG&E Corporation and the Utility expect to be the subject of numerous additional claims in connection with the 2018 Camp fire and 2017 Northern California wildfires. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. PG&E Corporation and the Utility are continuing to review the evidence concerning the 2018 Camp fire and 2017 Northern California wildfires. PG&E Corporation and the Utility have not yet had access to all of the evidence collected by Cal Fire as part of its investigations or to many of the investigation reports prepared by Cal Fire. PG&E Corporation and the Utility and plaintiffs are in discussions with Cal Fire about access to the evidence and the remaining reports. No schedule on gaining access has been set. (See “District Attorneys’ Offices’ Investigations” below for information regarding certain investigations related to the 2018 Camp fire and 2017 Northern California wildfires.) 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 resolved through the Chapter 11 process, regulatory proceedings and any potential enforcement proceedings, all of which could take a number of years to resolve. The timing and outcome of these and other potential proceedings are uncertain. PG&E Corporation and the Utility, as part of their efforts to emerge from bankruptcy, are engaged in discussions with holders of claims related to the 2017 Northern California wildfires and the 2018 Camp Fire in an attempt to reach a global settlement of such claims. PG&E Corporation and the Utility cannot predict the outcome or timing of such discussions. Even if discussions with claimholders were successful, the consummation of such an agreement would likely be contingent on numerous uncertain conditions, including Bankruptcy Court approval and governmental action. Potential Losses in Connection with the 2018 Camp Fire and 2017 Northern California Wildfires On January 28, 2019, the California Department of Insurance issued a news release announcing an update on property losses in connection with the 2018 wildfires in Southern California (which are not in the Utility’s service territory) and the 2018 Camp fire, stating that, as of such date, “more than $ 11.4 billion in insured losses have been reported from the November 2018 fires,” of which approximately $ 8.4 billion relates to statewide claims from the 2018 Camp fire. On September 6, 2018, the California Department of Insurance issued a news release announcing that insurers have received nearly 55,000 insurance claims totaling more than $ 12.28 billion in losses, of which approximately $ 10 billion relates to statewide claims from the 2017 Northern California wildfires. The dollar amounts announced by the California Department of Insurance represent an aggregate amount of approximately $ 18.4 billion of insurance claims made as of the above dates related to the 2018 Camp fire and 2017 Northern California wildfires. PG&E Corporation and the Utility expect that additional claims have been submitted and will continue to be submitted to insurers, particularly with respect to the 2018 Camp fire. These claims reflect insured property losses only. The $ 18.4 billion of insurance claims made as of the above dates does not account for uninsured or underinsured property losses, interest, attorneys’ fees, fire suppression and clean-up costs, evacuation costs, personal injury or wrongful death damages, medical expenses or other costs, such as potential punitive damages, fines or penalties, or losses related to claims that have not manifested yet (“future claims”), each of which could be significant. The scope of all claims related to the 2018 Camp fire and 2017 Northern California wildfires is not known at this time because of the applicable statutes of limitations under California law. Potential liabilities related to the 2018 Camp fire and 2017 Northern California wildfires depend on various factors, including but not limited to the cause of each fire, contributing causes of the fires (including alternative potential origins, weather and climate related issues), the number, size and type of structures damaged or destroyed, the contents of such structures and other personal property damage, the number and types of trees damaged or destroyed, attorneys’ fees for claimants, the nature and extent of any personal injuries, including the loss of lives, the extent to which future claims arise, the amount of fire suppression and clean-up costs, other damages the Utility may be responsible for if found negligent, the amount of any penalties or fines that may be imposed by governmental entities, and the amount of any penalties, fines, or restitution orders that might result from any criminal charges brought. There are a number of unknown facts and legal considerations that may impact the amount of any potential liability. Among other things, it is uncertain at this time as to the number of wildfire-related claims that will be filed in the Chapter 11 Cases, the number of current and future claims that will be allowed by the Bankruptcy Court, how claims for punitive damages and claims by variously situated persons will be treated and whether such claims will be allowed, and the impact that historical settlement values for wildfire claims may have on the estimation of wildfire liability in the Chapter 11 Cases. If PG&E Corporation and the Utility were to be found liable for certain or all of the costs, expenses and other losses described above with respect to the 2018 Camp fire and 2017 Northern California wildfires, the amount of such liability could exceed $ 30 billion, which amount does not include potential punitive damages, fines and penalties or damages related to future claims. This estimate is based on a wide variety of data and other information available to PG&E Corporation and the Utility and their advisors, including various precedents involving similar claims, and accounts for property losses (including insured, uninsured and underinsured property losses), interest, attorneys’ fees, fire suppression and clean-up costs, evacuation costs, personal injury or wrongful death damages, medical expenses and certain other costs. This estimate is not intended to provide an upper end of the range of potential liability arising from the 2018 Camp fire and 2017 Northern California wildfires. In certain circumstances, PG&E Corporation’s and the Utility’s liability could be substantially greater than such amount. If PG&E Corporation and the Utility were to be found liable for any punitive damages or subject to fines or penalties, the amount of such punitive damages, fines and penalties could be significant. PG&E Corporation and the Utility have received significant fines and penalties in connection with past incidents. For example, in 2015, the CPUC approved a decision that imposed penalties on the Utility totaling $ 1.6 billion in connection with the natural gas explosion that occurred in the City of San Bruno, California on September 9, 2010 (the “San Bruno explosion”). These penalties represented nearly three times the underlying liability for the San Bruno explosion of approximately $ 558 million incurred for third-party claims, exclusive of shareholder derivative lawsuits and legal costs incurred. The amount of punitive damages, fines and penalties imposed on PG&E Corporation and the Utility could likewise be a significant amount in relation to the underlying liabilities with respect to the 2018 Camp fire and 2017 Northern California wildfires. PG&E Corporation’s and the Utility’s obligations with respect to such claims are expected to be determined through the Chapter 11 process. Such proceedings are not subject to the automatic stay imposed as a result of the commencement of the Chapter 11 Cases; however, collection efforts in connection with fines or penalties arising out of such proceedings are stayed. 2018 Camp Fire and 2017 Northern California Wildfires Accounting Charge Following accounting rules, PG&E Corporation and the Utility record a liability when a loss is probable and reasonably estimable. In accordance with U.S. generally accepted accounting principles, 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 is the amount within the range that is a better estimate than any other amount 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. 2018 Camp Fire In light of the current state of the law and the information currently available to the Utility, including, among other things, the facts described in the EIRs and the 20 -Day Electric Incident Report, PG&E Corporation and the Utility have determined that it is probable they will incur a loss for claims in connection with the 2018 Camp fire, and accordingly PG&E Corporation and the Utility recorded a charge in the amount of $ 10.5 billion for the year ended December 31, 2018. This charge corresponds to the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimated losses, and is subject to change based on additional information. PG&E Corporation and the Utility currently believe that it is reasonably possible that the amount of the loss related to the 2018 Camp fire and 2017 Northern California wildfires will be greater than the amount accrued, but are unable to reasonably estimate the additional loss and the upper end of the range because there are a number of unknown facts and legal considerations that may impact the amount of any potential liability, including the total scope and nature of claims that may be asserted against PG&E Corporation and the Utility. PG&E Corporation and the Utility intend to continue to review the available information and other information as it becomes available, including evidence in Cal Fire’s possession, evidence from or held by other parties, claims that have not yet been submitted, and additional information about the nature and extent of personal and business property damage and losses, the nature, number and severity of personal injuries, and information made available through the discovery process. The process for estimating losses associated with claims requires management to exercise significant judgment based on a number of assumptions and subjective factors, including but not limited to factors identified above and estimates based on currently available information and prior experience with wildfires. As more information becomes available, management estimates and assumptions regarding the financial impact of the 2018 Camp fire may change, which could result in material increases to the loss accrued. The $ 10.5 billion charge does not include any amounts for potential penalties or fines that may be imposed by governmental entities on PG&E Corporation or the Utility, or punitive damages, if any, or any losses related to future claims for damages that have not manifested yet, each of which could be significant. 2017 Northern California Wildfires In light of the current state of the law on inverse condemnation and the information currently available to the Utility, including, among other things, the Cal Fire determinations of cause as stated in Cal Fire’s press releases and their released reports, PG&E Corporation and the Utility have determined that it is probable they will incur a loss for claims in connection with 17 of the 2017 Northern California wildfires referred to as the La Porte, McCourtney, Lobo, Honey, Redwood, Sulphur, Cherokee, Blue, Pocket, Atlas, Cascade, Point and Sonoma/Napa merged fires (which include the Nuns, Norrbom, Adobe, Partrick and Pythian fires). Accordingly, PG&E Corporation and the Utility recorded a charge in the amount of $ 2.5 billion during the quarter ended June 30, 2018 and a charge in the amount of $ 1.0 billion during the quarter ended December 31, 2018, for a total charge in the amount of $ 3.5 billion for the year ended December 31, 2018. This charge corresponds to the lower end of the range of PG&E Corporation’s and the Utility’s reasonably estimated losses and is subject to change based on additional information. PG&E Corporation and the Utility currently believe that it is reasonably possible that the amount of the loss related to the 2017 Northern California wildfires and the 2018 Camp fire will be greater than the amount accrued, but are unable to reasonably estimate the additional loss and the upper end of the range because there are a number of unknown facts and legal considerations that may impact the amount of any potential liability, including the total scope and nature of claims that ma

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	3 Months Ended
	Mar. 31, 2019
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 (consisting only of normal recurring 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, 2018 in the Condensed Consolidated Balance Sheets included in this quarterly report was derived from the audited Consolidated Balance Sheets in Item 8 of the 2018 Form 10-K. This quarterly report should be read in conjunction with the 2018 Form 10-K.
Use of Estimates and Assumptions	The preparation of financial statements in conformity with GAAP requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Some of the more significant estimates and assumptions relate to the Utility’s regulatory assets and liabilities, legal and regulatory contingencies, insurance recoveries, environmental remediation liabilities, AROs, pension and other post-retirement benefit plans obligations, and the valuation of pre-petition liabilities. 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 and results of operations 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, 2019 , 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, 2019 , it did not consolidate any of them.
Pension and Other Post-Retirement Benefits	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. 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.
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 Recognition of Lease Assets and Liabilities In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) , which amends the guidance relating to the definition of a lease, the recognition of lease assets and lease liabilities on the balance sheet, and the disclosure of key information about leasing arrangements. Under the new standard, all lessees must recognize a ROU asset, reflecting the right to use the underlying asset for the lease term, and a lease liability, reflecting the obligation to make lease payments, on the balance sheet. Operating leases were previously not recognized on the balance sheet. PG&E Corporation and the Utility adopted the ASU on January 1, 2019. PG&E Corporation and the Utility elected certain practical expedients and will carry forward historical conclusions related to (1) contracts that contain leases, (2) existing lease and easement classification, and (3) initial direct costs. After adoption of the new standard, the Corporation and Utility elected to not separate lease and non-lease components. Additionally, PG&E Corporation and the Utility have elected not to restate comparative periods upon adoption. PG&E Corporation and the Utility determine if an arrangement is a lease at inception. As most of the leases do not provide implicit discount rates, the Utility uses an estimate of its incremental secured borrowing rates based on observed market data and other information available at the lease commencement date. The ROU assets and lease liabilities include only fixed lease payments, and leases with an initial term of 12 months or less are not recorded on the balance sheet. Lease terms will only include options to extend or terminate the lease when it is reasonably certain that the Utility will exercise such options. The Utility recognizes lease expense in conformity with ratemaking. Operating leases are included in operating lease ROU assets and current and noncurrent operating lease liabilities on the Condensed Consolidated Balance Sheets. Finance leases are included in property, plant, and equipment, other current liabilities, and other noncurrent liabilities on the Condensed Consolidated Balance Sheets. Financing leases were immaterial for the three months ended March 31, 2019. Cash payments arising from operating leases were $335 million for the three months ended March 31, 2019 and are presented within operating activities on the Condensed Consolidated Statement of Cash Flows. Cash payments for the principal portion of the financing lease liability will continue to be presented within financing activities. Variable lease payments, if any, not included in the financing lease liability, if any, are presented within operating activities. On January 1, 2019, PG&E Corporation and the Utility recorded ROU assets and lease liabilities of $2.8 billion , representing the net present value of fixed lease payments and excluding any variable lease payments. This amount is presented within the supplemental disclosures of noncash activities for the three months ended, March 31, 2019. The majority of the Utility’s ROU assets and lease liabilities relate to various power purchase agreements. These power purchase agreements primarily consist of generation plants leased to meet customer demand plus applicable reserve margins, for terms between 5 years and 20 years . PG&E Corporation and the Utility have also recorded ROU assets and lease liabilities related to property and land leases. At March 31, 2019 , the Utility’s operating leases had a weighted average remaining lease term of 6.3 years and a weighted average discount rate of 6.11% . The following table shows the lease expense recognized for the fixed and variable component of the Utility’s lease obligations: (in millions) Three Months Ended March 31, 2019 Operating lease fixed cost $ 122 Operating lease variable cost 309 Total operating lease costs $ 431 The following table shows the Utility’s future expected operating lease payments: (in millions) March 31, 2019 2019 $ 686 2020 669 2021 616 2022 523 2023 195 Thereafter 672 Total lease payments 3,361 Less imputed interest (633 ) Total $ 2,728 The following table shows the Utility’s future expected obligations for power purchase and other lease commitments: (in millions) December 31, 2018 2019 $ 684 2020 677 2021 621 2022 546 2023 252 Thereafter 581 Total lease commitments $ 3,361 Accounting Standards Issued But Not Yet Adopted Fair Value Measurement In August 2018, the FASB issued ASU No. 2018-13, Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurements , which amends the existing guidance relating to the disclosure requirements for fair value measurements. The ASU will be effective for PG&E Corporation and the Utility on January 1, 2020 with early adoption permitted. PG&E Corporation and the Utility are currently evaluating the impact the guidance will have on their Condensed Consolidated Financial Statements and related disclosures. 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. This ASU will be effective for PG&E Corporation and the Utility on January 1, 2020 with early adoption permitted. 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 are 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.
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. 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.
Fair Value Measurement	PG&E Corporation and the Utility measure their cash equivalents, trust assets, and price risk management instruments at fair value. A three-tier fair value hierarchy is established that prioritizes the inputs to valuation methodologies used to measure fair value: • Level 1 – Observable inputs that reflect quoted prices (unadjusted) for identical assets or liabilities in active markets. • Level 2 – Other inputs that are directly or indirectly observable in the marketplace. • Level 3 – Unobservable inputs which are supported by little or no market activities. The fair value hierarchy requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value.
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. Transfers between levels in the fair value hierarchy are recognized as of the end of the reporting period. There were no material transfers between any levels for the three months ended March 31, 2019 and 2018 . 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
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 liability has been incurred and the amount of the liability can reasonably be 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. PG&E Corporation’s and the Utility’s provision for loss and expense excludes anticipated legal costs, which are expensed as incurred. The Utility also has substantial financial commitments in connection with agreements entered into to support its operating activities. PG&E Corporation’s and the Utility’s financial condition, results of operations, 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, 2019
Reorganizations [Abstract]
Schedule of Liabilities Subject to Compromise	The following table presents LSTC as reported in the Condensed Consolidated Balance Sheets at March 31, 2019 : (in millions) PG&E Corporation (1) Utility PG&E Corporation Consolidated Financing debt (2) $ 650 $ 21,811 $ 22,461 Wildfire-related claims (3) — 14,212 14,212 Trade creditors 1 1,850 1,851 Non-qualified benefit plan 122 17 139 2001 bankruptcy disputed claims — 221 221 Customer deposits & advances — 272 272 Other 2 164 166 Total Liabilities Subject to Compromise $ 775 $ 38,547 $ 39,322 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) At March 31, 2019 , PG&E Corporation and the Utility had $650 million and $21,526 million in aggregate principal amount of indebtedness, respectively. Utility financing debt also includes $285 million of accrued contractual interest to the Petition Date. See Note 5 for details of pre-petition debt reported as LSTC. (3) See Note 10 for details of pre-petition wildfire-related claims reported as LSTC.
Schedule of Debtor Reorganization Items	Reorganization items, net as of March 31, 2019 include the following: Post-Petition Period Through March 31, 2019 (in millions) PG&E Corporation (1) Utility PG&E Corporation Consolidated Debtor-in-possession financing costs 17 97 114 Legal and other $ 1 $ 23 $ 24 Interest income (2 ) (9 ) (11 ) Total reorganization items, net $ 16 $ 111 $ 127

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	3 Months Ended
	Mar. 31, 2019
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, 2019 and 2018 were as follows: Pension Benefits Other Benefits Three Months Ended March 31, (in millions) 2019 2018 2019 2018 Service cost for benefits earned (1) $ 111 $ 128 $ 14 $ 16 Interest cost 189 172 19 17 Expected return on plan assets (227 ) (255 ) (31 ) (33 ) Amortization of prior service cost (1 ) (1 ) 4 4 Amortization of net actuarial loss 1 1 (1 ) (1 ) Net periodic benefit cost 73 45 5 3 Regulatory account transfer (2) 10 39 — — Total $ 83 $ 84 $ 5 $ 3 (1) A portion of service costs are capitalized pursuant to ASU 2017-07. (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) are summarized below: Pension 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: Amortization of prior service cost (net of taxes of $0 and $1, respectively) (1) (1 ) 3 2 Amortization of net actuarial loss (net of taxes of $0 and $0, respectively) (1) 1 (1 ) — Regulatory account transfer (net of taxes of $0 and $1, respectively) (1) — (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.) Pension Benefits Other Total (in millions, net of income tax) Three Months Ended March 31, 2018 Beginning balance $ (25 ) $ 17 $ (8 ) 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 ) Reclassification of stranded income tax to retained earnings (net of taxes of $0 and $0, respectively) (5 ) — (5 ) Net current period other comprehensive gain (loss) (5 ) — (5 ) Ending balance $ (30 ) $ 17 $ (13 ) (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) 2019 2018 Electric Revenue from contracts with customers Residential $ 1,288 $ 1,336 Commercial 953 1,073 Industrial 293 324 Agricultural 86 125 Public street and highway lighting 17 20 Other (1) (309 ) (201 ) Total revenue from contracts with customers - electric 2,328 2,677 Regulatory balancing accounts (2) 464 274 Total electric operating revenue $ 2,792 $ 2,951 Natural gas Revenue from contracts with customers Residential $ 1,171 $ 958 Commercial 240 196 Transportation service only 382 297 Other (1) (75 ) (52 ) Total revenue from contracts with customers - gas 1,718 1,399 Regulatory balancing accounts (2) (499 ) (294 ) Total natural gas operating revenue 1,219 1,105 Total operating revenues $ 4,011 $ 4,056 (1) This activity is primarily related to the change in unbilled revenue, partially offset by other miscellaneous revenue items. (2) These amounts represent revenues authorized to be billed or refunded to customers.
Schedule of Lease Expense	The following table shows the lease expense recognized for the fixed and variable component of the Utility’s lease obligations: (in millions) Three Months Ended March 31, 2019 Operating lease fixed cost $ 122 Operating lease variable cost 309 Total operating lease costs $ 431
Schedule of Future Expected Operating Lease Payments and Expected Obligations for Power Purchase and Other Lease Commitments	The following table shows the Utility’s future expected operating lease payments: (in millions) March 31, 2019 2019 $ 686 2020 669 2021 616 2022 523 2023 195 Thereafter 672 Total lease payments 3,361 Less imputed interest (633 ) Total $ 2,728 The following table shows the Utility’s future expected obligations for power purchase and other lease commitments: (in millions) December 31, 2018 2019 $ 684 2020 677 2021 621 2022 546 2023 252 Thereafter 581 Total lease commitments $ 3,361

REGULATORY ASSETS, LIABILITIE_2

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Tables)	3 Months Ended
	Mar. 31, 2019
Regulated Operations [Abstract]
Long-Term Regulatory Assets	Long-term regulatory assets are comprised of the following: Asset Balance at (in millions) March 31, 2019 December 31, 2018 Pension benefits (1) $ 1,938 $ 1,947 Environmental compliance costs 932 1,013 Utility retained generation (2) 262 274 Price risk management 65 90 Unamortized loss, net of gain, on reacquired debt (3) 237 76 Catastrophic event memorandum account (4) 865 790 Wildfire expense memorandum account (5) 111 94 Fire hazard prevention memorandum account (6) 329 263 Other 412 417 Total long-term regulatory assets $ 5,151 $ 4,964 (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 the accelerated amortization of premiums and debt issuance costs on pre-petition debt. (4) 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. (5) Includes specific incremental wildfire liability costs the CPUC approved for tracking in June 2018. Recovery of WEMA costs are subject to CPUC review and approval. (6) 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.
Long-Term Regulatory Liabilities	Long-term regulatory liabilities are comprised of the following: Liability Balance at (in millions) March 31, 2019 December 31, 2018 Cost of removal obligations (1) $ 6,134 $ 5,981 Deferred income taxes (2) 142 283 Recoveries in excess of AROs (3) 471 356 Public purpose programs (4) 758 674 Retirement Plan (5) 422 421 Other 945 824 Total long-term regulatory liabilities $ 8,872 $ 8,539 (1) Represents the cumulative differences between asset removal costs recorded and amounts collected in rates for expected asset removal costs. (2) Represents the net of amounts owed to customers for deferred taxes collected at higher rates before the Tax Act and amounts owed to the Utility for reversal of deferred taxes subject to flow-through treatment. (3) 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.) (4) 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. (5) 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 Receivable	Current regulatory balancing accounts receivable and payable are comprised of the following: Receivable Balance at (in millions) March 31, 2019 December 31, 2018 Electric distribution $ 449 $ 160 Electric transmission 128 128 Utility generation 357 79 Gas distribution and transmission 70 462 Energy procurement 137 168 Public purpose programs 76 111 Other 280 327 Total regulatory balancing accounts receivable $ 1,497 $ 1,435
Regulatory Balancing Accounts Payable	Payable Balance at (in millions) March 31, 2019 December 31, 2018 Electric transmission 146 134 Gas distribution and transmission 51 9 Energy procurement 223 59 Public purpose programs 600 587 Other 325 287 Total regulatory balancing accounts payable $ 1,345 $ 1,076

DEBT (Tables)

DEBT (Tables)	3 Months Ended
	Mar. 31, 2019
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, 2019 : (in millions) Termination Date Limit Letters of Credit Outstanding Borrowings Against DIP Revolving Facility Availability DIP Facilities December 2020 (1) $ 1,500 (2) $ 131 $ 350 $ 1,019 (1) May be extended to December 2021, subject to satisfaction of certain terms and conditions, including payment of a 25 basis point extension fee. (2) On March 27, 2019, the Bankruptcy Court approved the DIP Facilities in full, but the conditions precedent to the full availability of the DIP Facilities were not satisfied until April 3, 2019. Accordingly, the amounts set forth in this table are based on the interim availability under the DIP Revolving Facility of $1.5 billion .
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, 2019 December 31, 2018 Debt Subject to Compromise (1) PG&E Corporation Borrowings under Pre-Petition Credit Facilities PG&E Corporation Revolving Credit Facilities - Stated Maturity: 2022 variable rate (2) $ 300 $ 300 Other borrowings: Term Loan - Stated Maturity: 2020 variable rate (3) 350 350 Total PG&E Corporation Debt Subject to Compromise 650 650 Utility Senior Notes - Stated Maturity: 2020 3.50% 800 800 2021 3.25% to 4.25% 550 550 2022 2.45% 400 400 2023 3.25% to 4.25% 1,175 1,175 2024 through 2046 2.95% to 6.35% 14,600 14,600 Unamortized discount, net or premium and debt issuance costs — (178 ) Total Senior notes, net of premium and debt issuance costs 17,525 17,347 Pollution Control Bonds - Stated Maturity: Series 2008 F and 2010 E, due 2026 (4) 1.75% 100 100 Series 2009 A-B, due 2026 (5) variable rate (6) 149 149 Series 1996 C, E, F, 1997 B due 2026 (5) variable rate (7) 614 614 Total pollution control bonds 863 863 Borrowings under Pre-Petition Credit Facilities Utility Revolving Credit Facilities - Stated Maturity: 2022 (8) variable rate (9) 2,965 2,965 Other borrowings: Term Loan - Stated Maturity: 2019 variable rate (10) 250 250 Total Borrowings under Pre-Petition Credit Facility Subject to Compromise 3,215 3,215 Total Utility Debt Subject to Compromise 21,603 21,425 Total PG&E Corporation Consolidated Debt Subject to Compromise $ 22,253 $ 22,075 (1) LSTC must be reported at the amounts expected to be allowed by the Bankruptcy Court. The carrying value of the debt subject to compromise will be adjusted as claims are approved. As of March 31, 2019 , PG&E Corporation and the Utility wrote off $178 million of unamortized debt issuance costs and debt discount to present the debt subject to compromise at the outstanding face value. The write-offs are included within long-term regulatory assets in the Condensed Consolidated Statements of Income. See Notes 2 and 4 for further details. (2) At March 31, 2019 , the contractual LIBOR-based interest rate on loans were 3.97% . (3) At March 31, 2019 , the contractual LIBOR-based interest rate on the term loan was 3.71% . (4) 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. (5) 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 has a maturity date of 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. (6) At March 31, 2019, the contractual interest rate on the letter of credit facility supporting these bonds was 4.13% . (7) At March 31, 2019 , the contractual interest rate on the letter of credit facility supporting these bonds ranged from 4.13% to 4.47% . (8) Also includes $80 million in letters of credit. (9) At March 31, 2019 , the contractual LIBOR-based interest rate was 3.67% . (10) At March 31, 2019 , the contractual LIBOR-based interest rate was 3.09% .

EQUITY (Tables)

EQUITY (Tables)	3 Months Ended
	Mar. 31, 2019
Stockholders' Equity Note [Abstract]
Changes in Equity	PG&E Corporation’s changes in equity for the three months ended March 31, 2019 and 2018 were as follows: (in millions, except share amounts) Common Stock Shares Common Stock Amount Reinvested Earnings Accumulated Other Comprehensive Income (Loss) Total Shareholders’ Equity Non controlling Interest - Preferred Stock of Subsidiary Total Equity Balance at December 31, 2018 520,338,710 $ 12,910 $ (250 ) $ (9 ) $ 12,651 $ 252 $ 12,903 Net income (loss) — — 136 — 136 — 136 Other comprehensive loss — — — — — — — Common stock issued, net 8,871,568 85 — — 85 — 85 Stock-based compensation amortization — 5 — — 5 — 5 Balance at March 31, 2019 529,210,278 $ 13,000 $ (114 ) $ (9 ) $ 12,877 $ 252 $ 13,129 (in millions, except share amounts) Common Stock Shares Common Stock Amount Reinvested Earnings Accumulated Other Comprehensive Income (Loss) Total Shareholders’ Equity Non controlling Interest - Preferred Stock of Subsidiary Total Equity Balance at December 31, 2017 514,775,845 $ 12,632 $ 6,596 $ (8 ) $ 19,220 $ 252 $ 19,472 Net income — — 445 — 445 — 445 Other comprehensive income — — — — — — — Common stock issued, net 1,248,112 35 — — 35 — 35 Stock-based compensation amortization — 34 — — 34 — 34 Preferred stock dividend requirement of subsidiary — — (3 ) — (3 ) — (3 ) Balance at March 31, 2018 516,023,957 $ 12,701 $ 7,038 $ (8 ) $ 19,731 $ 252 $ 19,983 The Utility’s changes in equity for the three months ended March 31, 2019 and 2018 were as follows: (in millions) Preferred Stock Common Additional Paid-in Capital Reinvested Earnings Accumulated Other Comprehensive Income (Loss) Total Shareholders’ Equity Balance at December 31, 2018 $ 258 $ 1,322 $ 8,550 $ 2,826 $ (1 ) $ 12,955 Net income (loss) — — — 133 — 133 Other comprehensive loss — — — — — — Equity contribution — — — — — — Preferred stock dividend — — — — — — Balance at March 31, 2019 $ 258 $ 1,322 $ 8,550 $ 2,959 $ (1 ) $ 13,088 (in millions) Preferred Stock Common Additional Paid-in Capital Reinvested Earnings Accumulated Other Comprehensive Income (Loss) Total Shareholders’ Equity Balance at December 31, 2017 258 1,322 8,505 9,656 6 $ 19,747 Net income — — — 452 — 452 Other comprehensive income — — — 2 (2 ) — Equity contribution — — — — — — Common stock dividend — — — — — — Preferred stock dividend — — — (3 ) — (3 ) Balance at March 31, 2018 $ 258 $ 1,322 $ 8,505 $ 10,107 $ 4 $ 20,196

EARNINGS PER SHARE (Tables)

EARNINGS PER SHARE (Tables)	3 Months Ended
	Mar. 31, 2019
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) 2019 2018 Income available for common shareholders $ 136 $ 445 Preferred stock dividend requirement of subsidiary 3 3 Adjusted income available for common shareholders 133 442 Weighted average common shares outstanding, basic 526 515 Add incremental shares from assumed conversions: Employee share-based compensation 1 1 Weighted average common shares outstanding, diluted 527 516 Total earnings per common share, diluted $ 0.25 $ 0.86

DERIVATIVES (Tables)

DERIVATIVES (Tables)	3 Months Ended
	Mar. 31, 2019
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, December 31, Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 138,016,980 177,750,349 Options 4,115,000 13,735,405 Electricity (Megawatt-hours) Forwards, Futures and Swaps 3,011,826 3,833,490 Congestion Revenue Rights (3) 335,556,726 340,783,089 (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, 2019 , the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Balance Netting Cash Collateral Total Derivative Balance Current assets – other $ 45 $ (2 ) $ 38 $ 81 Other noncurrent assets – other 165 1 — 166 Current liabilities – other (37 ) 17 3 (17 ) Noncurrent liabilities – other (49 ) (16 ) — (65 ) Total commodity risk $ 124 $ — $ 41 $ 165 At December 31, 2018 , the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Balance Netting Cash Collateral Total Derivative Balance Current assets – other $ 44 $ (1 ) $ 89 $ 132 Other noncurrent assets – other 165 — — 165 Current liabilities – other (29 ) 1 7 (21 ) Noncurrent liabilities – other (90 ) — 2 (88 ) Total commodity risk $ 90 $ — $ 98 $ 188
Schedule of Offsetting Liabilities	At March 31, 2019 , the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Balance Netting Cash Collateral Total Derivative Balance Current assets – other $ 45 $ (2 ) $ 38 $ 81 Other noncurrent assets – other 165 1 — 166 Current liabilities – other (37 ) 17 3 (17 ) Noncurrent liabilities – other (49 ) (16 ) — (65 ) Total commodity risk $ 124 $ — $ 41 $ 165 At December 31, 2018 , the Utility’s outstanding derivative balances were as follows: Commodity Risk (in millions) Gross Derivative Balance Netting Cash Collateral Total Derivative Balance Current assets – other $ 44 $ (1 ) $ 89 $ 132 Other noncurrent assets – other 165 — — 165 Current liabilities – other (29 ) 1 7 (21 ) Noncurrent liabilities – other (90 ) — 2 (88 ) Total commodity risk $ 90 $ — $ 98 $ 188

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	3 Months Ended
	Mar. 31, 2019
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, 2019 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 2,898 $ — $ — $ — $ 2,898 Nuclear decommissioning trusts Short-term investments 18 — — — 18 Global equity securities 1,882 — — — 1,882 Fixed-income securities 790 692 — — 1,482 Assets measured at NAV — — — — 18 Total nuclear decommissioning trusts (2) 2,690 692 — — 3,400 Price risk management instruments (Note 8) Electricity — 1 209 15 225 Gas — — — 22 22 Total price risk management instruments — 1 209 37 247 Rabbi trusts Fixed-income securities — 96 — — 96 Life insurance contracts — 69 — — 69 Total rabbi trusts — 165 — — 165 Long-term disability trust Short-term investments 8 — — — 8 Assets measured at NAV — — — — 146 Total long-term disability trust 8 — — — 154 TOTAL ASSETS $ 5,596 $ 858 $ 209 $ 37 $ 6,864 Liabilities: Price risk management instruments (Note 8) Electricity $ 1 $ 3 $ 80 $ (4 ) $ 80 Gas — 2 — — 2 TOTAL LIABILITIES $ 1 $ 5 $ 80 $ (4 ) $ 82 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $468 million , primarily related to deferred taxes on appreciation of investment value. Fair Value Measurements December 31, 2018 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 1,593 $ — $ — $ — $ 1,593 Nuclear decommissioning trusts Short-term investments 29 — — — 29 Global equity securities 1,793 — — — 1,793 Fixed-income securities 661 639 — — 1,300 Assets measured at NAV — — — — 16 Total nuclear decommissioning trusts (2) 2,483 639 — — 3,138 Price risk management instruments (Note 8) Electricity — 5 203 51 259 Gas — 1 — 37 38 Total price risk management instruments — 6 203 88 297 Rabbi trusts Fixed-income securities — 93 — — 93 Life insurance contracts — 67 — — 67 Total rabbi trusts — 160 — — 160 Long-term disability trust Short-term investments 7 — — — 7 Assets measured at NAV — — — — 155 Total long-term disability trust 7 — — — 162 TOTAL ASSETS $ 4,083 $ 805 $ 203 $ 88 $ 5,350 Liabilities: Price risk management instruments (Note 8) Electricity $ 4 $ 5 $ 108 $ (10 ) $ 107 Gas — 2 — — 2 TOTAL LIABILITIES $ 4 $ 7 $ 108 $ (10 ) $ 109 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $408 million , primarily related to deferred taxes on appreciation of investment value.
Level 3 Measurements and Sensitivity Analysis	Fair Value at (in millions) March 31, 2019 Fair Value Measurement Assets Liabilities Valuation Unobservable Range (1) Congestion revenue rights $ 203 $ 60 Market approach CRR auction prices $(36.87) - 23.04 Power purchase agreements $ 6 $ 20 Discounted cash flow Forward prices $ 19.81 - 38.80 (1) Represents price per megawatt-hour. Fair Value at (in millions) December 31, 2018 Fair Value Measurement Assets Liabilities Valuation Technique Unobservable Input Range (1) Congestion revenue rights $ 203 $ 75 Market approach CRR auction prices $ (18.61) - 32.26 Power purchase agreements $ — $ 33 Discounted cash flow Forward prices $ 19.81 - 38.80 (1) Represents price per megawatt-hour.
Level 3 Reconciliation	The following tables present the reconciliation for Level 3 price risk management instruments for the three months ended March 31, 2019 and 2018 : Price Risk Management Instruments (in millions) 2019 2018 Asset (liability) balance as of January 1 $ 95 $ 42 Net realized and unrealized gains: Included in regulatory assets and liabilities or balancing accounts (1) 34 (2 ) Asset (liability) balance as of March 31 $ 129 $ 40 (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 debt instruments were as follows (the table below excludes financial instruments with carrying values that approximate their fair values): At March 31, 2019 At December 31, 2018 (in millions) Carrying Amount Level 2 Fair Value Carrying Amount Level 2 Fair Value PG&E Corporation (1) — — $ 350 $ 350 Utility (1)(2) 350 350 17,450 14,747 (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 4. (2) The Utility drew $350 million from the DIP Revolving Facility on February 1, 2019 which was subsequently repaid on April 3, 2019 using certain of the proceeds of the DIP Initial Term Loan Facility.
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, 2019 Amortized Total Unrealized Gains Total Unrealized Losses Total Fair Nuclear decommissioning trusts Short-term investments $ 18 $ — $ — $ 18 Global equity securities 481 1,422 (3 ) 1,900 Fixed-income securities 1,432 58 (8 ) 1,482 Total (1) $ 1,931 $ 1,480 $ (11 ) $ 3,400 As of December 31, 2018 Nuclear decommissioning trusts Short-term investments $ 29 $ — $ — $ 29 Global equity securities 568 1,246 (5 ) 1,809 Fixed-income securities 1,288 30 (18 ) 1,300 Total (1) $ 1,885 $ 1,276 $ (23 ) $ 3,138 (1) Represents amounts before deducting $468 million and $408 million for the periods ended March 31, 2019 and December 31, 2018 , 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, 2019 Less than 1 year $ 31 1–5 years 534 5–10 years 337 More than 10 years 580 Total maturities of fixed-income securities $ 1,482
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) 2019 2018 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 346 $ 494 Gross realized gains on securities (34 ) 37 Gross realized losses on securities 19 (4 )

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES (Tables)	3 Months Ended
	Mar. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Schedule of Environmental Remediation Liability	At March 31, 2019 and December 31, 2018 , the Utility’s Condensed Consolidated Balance Sheets include estimated liabilities in respect of total wildfire-related claims as follows: Balance at (in millions) March 31, 2019 December 31, 2018 2015 Butte fire $ 212 $ 226 2017 Northern California wildfires 3,500 3,500 2018 Camp fire 10,500 10,500 Total wildfire-related claims (1) $ 14,212 $ 14,226 (1) On the Petition Date all wildfire-related claims were classified as subject to compromise and all pending litigation was stayed. (For more information see Note 2 of the Condensed Consolidated Financial Statements.)
Changes in Insurance Receivable	The following table presents changes in the insurance receivable since December 31, 2015. The balance for the insurance receivable is included in Other accounts receivable in PG&E Corporation’s and the Utility’s Condensed Consolidated Balance Sheets: Insurance Receivable (in millions) Balance at December 31, 2015 $ — Accrued insurance recoveries 625 Reimbursements (50) Balance at December 31, 2016 575 Accrued insurance recoveries 297 Reimbursements (276) Balance at December 31, 2017 596 Accrued insurance recoveries — Reimbursements (511 ) Balance at December 31, 2018 85 Accrued insurance recoveries — Reimbursements (25 ) Balance as of March 31, 2019 $ 60
Change in Accruals Related to Third-Party Claims	The following table presents changes in the insurance receivable for the three months ended March 31, 2019 . The balance for insurance receivable is included in Other accounts receivable in PG&E Corporation’s and the Utility’s Condensed Consolidated Balance Sheets: (in millions) Insurance Receivable 2018 Camp fire Balance at December 31, 2018 $ 1,380 Accrued insurance recoveries $ — Reimbursements — Balance at March 31, 2019 $ 1,380 2017 Northern California wildfires Balance at December 31, 2018 $ 829 Accrued insurance recoveries — Reimbursements — Balance at March 31, 2019 $ 829 The following table presents changes in the third-party claims liability since December 31, 2015. The balance for the third-party claims liability is included in Wildfire-related claims in PG&E Corporation’s and the Utility’s Condensed Consolidated Balance Sheets: Loss Accrual (in millions) Balance at December 31, 2015 $ — Accrued losses 750 Payments (1) (60) Balance at December 31, 2016 690 Accrued losses 350 Payments (1) (479) Balance at December 31, 2017 561 Accrued losses — Payments (1) (335 ) Balance at December 31, 2018 226 Accrued losses — Payments (1) (14 ) Balance as of March 31, 2019 $ 212 (1) As of March 31, 2019 , the Utility has paid $ 888 million of the $ 904 million in settlements to date in connection with the 2015 Butte fire.

OTHER CONTINGENCIES AND COMMI_2

OTHER CONTINGENCIES AND COMMITMENTS (Tables)	3 Months Ended
	Mar. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Schedule of Environmental Remediation Liability	The Utility’s environmental remediation liability is primarily included in non-current liabilities on the Condensed Consolidated Balance Sheets and is comprised of the following: Balance at March 31, December 31, (in millions) 2019 2018 Topock natural gas compressor station $ 358 $ 369 Hinkley natural gas compressor station 145 146 Former manufactured gas plant sites owned by the Utility or third parties (1) 525 520 Utility-owned generation facilities (other than fossil fuel-fired), (2) 107 111 Fossil fuel-fired generation facilities and sites (3) 131 137 Total environmental remediation liability $ 1,266 $ 1,283 (1) Primarily driven by the following sites: Vallejo, San Francisco East Harbor, Napa, Beach Street, and San Francisco North Beach. (2) Primarily driven by the Geothermal landfill and Shell Pond site. (3) Primarily driven by the San Francisco Potrero Power Plant.

ORGANIZATION AND BASIS OF PRE_2

ORGANIZATION AND BASIS OF PRESENTATION (Narrative) (Details)	3 Months Ended
	Mar. 31, 2019segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of operating segments (segment)	1

BANKRUPTCY FILING (Narrative) (

BANKRUPTCY FILING (Narrative) (Details) - USD ($)	2 Months Ended	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2019	Feb. 01, 2019	Jan. 31, 2019
Debt Instrument [Line Items]
Contractual interest expense on prepetition liabilities not recorded in financial statements	$ 166,000,000
DIP Credit Agreement | Line of Credit | Senior Secured Superpriority Debt
Debt Instrument [Line Items]
Amount arranged			$ 5,500,000,000	$ 5,500,000,000
Pacific Gas & Electric Co
Debt Instrument [Line Items]
Payments for reorganization items		$ 91,000,000
PG&E Corporation
Debt Instrument [Line Items]
Payments for reorganization items		$ 17,000,000

BANKRUPTCY FILING (Schedule of

BANKRUPTCY FILING (Schedule of Liabilities Subject to Compromise) (Details) - USD ($)	Mar. 31, 2019	Dec. 31, 2018
Reorganizations [Line Items]
Financing debt	$ 22,461,000,000
Wildfire-related claims	14,212,000,000
Trade creditors	1,851,000,000
Non-qualified benefit plan	139,000,000
2001 bankruptcy disputed claims	221,000,000
Customer deposits & advances	272,000,000
Other	166,000,000
Total Liabilities Subject to Compromise	39,322,000,000	$ 0
Pacific Gas & Electric Co
Reorganizations [Line Items]
Financing debt	21,811,000,000
Wildfire-related claims	14,212,000,000
Trade creditors	1,850,000,000
Non-qualified benefit plan	17,000,000
2001 bankruptcy disputed claims	221,000,000
Customer deposits & advances	272,000,000
Other	164,000,000
Total Liabilities Subject to Compromise	38,547,000,000	$ 0
Debt subject to compromise, aggregate principal amount	21,526
Accrued contractual interest subject to compromise	285,000,000
PG&E Corporation
Reorganizations [Line Items]
Financing debt	650,000,000
Wildfire-related claims	0
Trade creditors	1,000,000
Non-qualified benefit plan	122,000,000
2001 bankruptcy disputed claims	0
Customer deposits & advances	0
Other	2,000,000
Total Liabilities Subject to Compromise	775,000,000
Debt subject to compromise, aggregate principal amount	$ 650,000,000

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, 2019	Mar. 31, 2018
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	$ 111	$ 128
Interest cost	189	172
Expected return on plan assets	(227)	(255)
Amortization of prior service cost	(1)	(1)
Amortization of net actuarial loss	1	1
Net periodic benefit cost	73	45
Regulatory account transfer	10	39
Total	83	84
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	14	16
Interest cost	19	17
Expected return on plan assets	(31)	(33)
Amortization of prior service cost	4	4
Amortization of net actuarial loss	(1)	(1)
Net periodic benefit cost	5	3
Regulatory account transfer	0	0
Total	$ 5	$ 3

BANKRUPTCY FILING (Schedule o_2

BANKRUPTCY FILING (Schedule of Debtor Reorganization Items) (Details) - USD ($) $ in Millions	2 Months Ended	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2019	Mar. 31, 2018
Reorganizations [Line Items]
Debtor-in-possession financing costs	$ 114
Legal and other	24
Interest income	(11)
Total reorganization items, net	127	$ 127	$ 0
Pacific Gas & Electric Co
Reorganizations [Line Items]
Debtor-in-possession financing costs	97
Legal and other	23
Interest income	(9)
Total reorganization items, net	111	$ 111	$ 0
PG&E Corporation
Reorganizations [Line Items]
Debtor-in-possession financing costs	17
Legal and other	1
Interest income	(2)
Total reorganization items, net	$ 16

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, 2019	Mar. 31, 2018
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	$ 12,903	$ 19,472
Net current period other comprehensive gain (loss)	0	(5)
Ending balance	13,129	19,983
Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Net current period other comprehensive gain (loss)	0	(5)
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	(4)	(8)
Ending balance	(4)	(13)
Accumulated Other Comprehensive Income (Loss) | Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(21)	(25)
Ending balance	(21)	(30)
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 benefit (cost)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	2	2
Amortization of prior service benefit (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 benefit (cost) | Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	3	3
Amount attributable to tax	1	1
Amortization of net actuarial gain (loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	0	0
Amortization of net actuarial gain (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 gain (loss) | Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(1)	(1)
Amount attributable to tax	0	0
Regulatory account transfer
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(2)	(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	(2)	(2)
Amount attributable to tax	$ 1	1
Reclassification of stranded income tax to retained earnings
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income		(5)
Reclassification of stranded income tax to retained earnings | Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income		(5)
Amount attributable to tax		0
Reclassification of stranded income tax to retained earnings | Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income		0
Amount attributable to tax		$ 0

SUMMARY OF SIGNIFICANT ACCOUN_6

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Jan. 01, 2019
Lessee, Lease, Description [Line Items]
Period for probable revenue recovery	24 months
Operating lease, cash payments	$ 335
Operating lease right of use asset	2,738
Operating lease, liability	$ 2,728
Operating lease, weighted average remaining lease term	6 years 4 months
Operating lease, weighted average discount rate, percent	6.11%
Minimum
Lessee, Lease, Description [Line Items]
Lessee, operating lease, term of contract	5 years
Maximum
Lessee, Lease, Description [Line Items]
Lessee, operating lease, term of contract	20 years
Accounting Standards Update 2016-02
Lessee, Lease, Description [Line Items]
Operating lease right of use asset		$ 2,800
Operating lease, liability		$ 2,800

SUMMARY OF SIGNIFICANT ACCOUN_7

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Revenues Disaggregated by Type of Customer) (Details) - Pacific Gas & Electric Co - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Revenue from contracts with customers
Total operating revenues	$ 4,011	$ 4,056
Electric
Revenue from contracts with customers
Total revenue from contracts with customers	2,328	2,677
Regulatory balancing accounts	464	274
Total operating revenues	2,792	2,951
Electric | Residential
Revenue from contracts with customers
Total revenue from contracts with customers	1,288	1,336
Electric | Commercial
Revenue from contracts with customers
Total revenue from contracts with customers	953	1,073
Electric | Industrial
Revenue from contracts with customers
Total revenue from contracts with customers	293	324
Electric | Agricultural
Revenue from contracts with customers
Total revenue from contracts with customers	86	125
Electric | Public street and highway lighting
Revenue from contracts with customers
Total revenue from contracts with customers	17	20
Electric | Other
Revenue from contracts with customers
Total revenue from contracts with customers	(309)	(201)
Natural gas
Revenue from contracts with customers
Total revenue from contracts with customers	1,718	1,399
Regulatory balancing accounts	(499)	(294)
Total operating revenues	1,219	1,105
Natural gas | Residential
Revenue from contracts with customers
Total revenue from contracts with customers	1,171	958
Natural gas | Commercial
Revenue from contracts with customers
Total revenue from contracts with customers	240	196
Natural gas | Transportation service only
Revenue from contracts with customers
Total revenue from contracts with customers	382	297
Natural gas | Other
Revenue from contracts with customers
Total revenue from contracts with customers	$ (75)	$ (52)

SUMMARY OF SIGNIFICANT ACCOUN_8

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Schedule of Lease Expense) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)
Accounting Policies [Abstract]
Operating lease fixed cost	$ 122
Operating lease variable cost	309
Total operating lease costs	$ 431

SUMMARY OF SIGNIFICANT ACCOUN_9

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Future Expected Operating Lease Payments and Expected Obligations for Power Purchase and Other Lease Commitments) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Future Expected Operating Lease Payments
2019	$ 686
2020	669
2021	616
2022	523
2023	195
Thereafter	672
Total lease payments	3,361
Less imputed interest	(633)
Total	$ 2,728
Future Expected Minimum Lease Commitments
2019		$ 684
2020		677
2021		621
2022		546
2023		252
Thereafter		581
Total lease commitments		$ 3,361

REGULATORY ASSETS, LIABILITIE_3

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Assets) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 5,151	$ 4,964
Retained generation asset costs	1,200
Pension benefits
Regulatory Assets [Line Items]
Total long-term regulatory assets	1,938	1,947
Environmental compliance costs
Regulatory Assets [Line Items]
Total long-term regulatory assets	932	1,013
Utility retained generation
Regulatory Assets [Line Items]
Total long-term regulatory assets	262	274
Price risk management
Regulatory Assets [Line Items]
Total long-term regulatory assets	65	90
Unamortized loss, net of gain, on reacquired debt
Regulatory Assets [Line Items]
Total long-term regulatory assets	237	76
Catastrophic event memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	865	790
Wildfire expense memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	111	94
Fire hazard prevention memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	329	263
Other
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 412	$ 417

REGULATORY ASSETS, LIABILITIE_4

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Liabilities) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 8,872	$ 8,539
Cost of removal obligations
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	6,134	5,981
Deferred income taxes
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	142	283
Recoveries in excess of AROs
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	471	356
Public purpose programs
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	758	674
Retirement Plan
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	422	421
Other
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 945	$ 824

REGULATORY ASSETS, LIABILITIE_5

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Current Regulatory Balancing Accounts, Net) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Total regulatory balancing accounts receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	$ 1,497	$ 1,435
Total regulatory balancing accounts receivable | Electric distribution
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	449	160
Total regulatory balancing accounts receivable | Electric transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	128	128
Total regulatory balancing accounts receivable | Utility generation
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	357	79
Total regulatory balancing accounts receivable | Gas distribution and transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	70	462
Total regulatory balancing accounts receivable | Energy procurement
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	137	168
Total regulatory balancing accounts receivable | Public purpose programs
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	76	111
Total regulatory balancing accounts receivable | Other
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	280	327
Total regulatory balancing accounts payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	1,345	1,076
Total regulatory balancing accounts payable | Electric transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	146	134
Total regulatory balancing accounts payable | Gas distribution and transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	51	9
Total regulatory balancing accounts payable | Energy procurement
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	223	59
Total regulatory balancing accounts payable | Public purpose programs
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	600	587
Total regulatory balancing accounts payable | Other
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	$ 325	$ 287

DEBT (Debtor In Possession ("DI

DEBT (Debtor In Possession ("DIP") Facilities and Financing) (Details)	Apr. 03, 2019USD ($)	Mar. 31, 2019USD ($)	Feb. 01, 2019USD ($)	Jan. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Line of Credit Facility [Line Items]
Debtor-in-possession financing		$ 350,000,000			$ 0
Commercial Paper		0
Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Debtor-in-possession financing		350,000,000			0
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	$ 5,500,000,000
DIP Revolving Facility | Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Letters of Credit Outstanding		80,000,000
Borrowings Against DIP Revolving Facility		2,965,000,000			$ 2,965,000,000
DIP Revolving Facility | DIP Credit Agreement | Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Limit		1,500,000,000
Letters of Credit Outstanding		131,000,000
Borrowings Against DIP Revolving Facility		350,000,000
Availability		$ 1,019,000,000
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			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 | Line of Credit | DIP Credit Agreement
Line of Credit Facility [Line Items]
Amount arranged			500,000,000
DIP Delayed Draw Term Loan Facility | Line of Credit | DIP Credit Agreement | Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Amount arranged			$ 350,000,000
Subsequent Event | DIP Initial Term Loan Facility | Line of Credit | DIP Credit Agreement | Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Amount arranged	$ 1,500,000,000
Subsequent Event | DIP Delayed Draw Term Loan Facility | Line of Credit | DIP Credit Agreement | Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Repayments of debt	$ 350,000,000

DEBT (Schedule of Long-term Deb

DEBT (Schedule of Long-term Debt) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Debt [Line Items]
Debt subject to compromise	$ 22,253	$ 22,075
Debtor reorganization items, write-off of debt issuance costs and debt discounts	178
Pacific Gas & Electric Co
Debt [Line Items]
Debt subject to compromise	21,603	21,425
Long-term debt	3,215	3,215
Pollution control bonds	863	863
PG&E Corporation
Debt [Line Items]
Debt subject to compromise	650	650
Term Loan Due 2020 | PG&E Corporation
Debt [Line Items]
Debt subject to compromise	$ 350	350
Interest rate at period end	3.71%
Senior Notes Due 2020 | Pacific Gas & Electric Co
Debt [Line Items]
Contractual Interest Rates	3.50%
Senior Notes Due 2022 | Pacific Gas & Electric Co
Debt [Line Items]
Contractual Interest Rates	2.45%
Pollution Control Bonds Series 2008, F, And 2010, E, 1.75%, Due 2026 | Pacific Gas & Electric Co
Debt [Line Items]
Contractual Interest Rates	1.75%
Pollution control bonds	$ 100	100
Pollution Control Bonds Series 2009, A-B, Variable Rate, Due 2026 | Pacific Gas & Electric Co
Debt [Line Items]
Pollution control bonds	149	149
Pollution Control Bonds, Series 1996 C,E,F 1997 B, Variable Rates, Due 2026 | Pacific Gas & Electric Co
Debt [Line Items]
Pollution control bonds	614	614
Term Loan Due 2019 | Pacific Gas & Electric Co
Debt [Line Items]
Other borrowings	$ 250	250
Interest rate at period end	3.09%
Revolving Credit Facility | Pacific Gas & Electric Co
Debt [Line Items]
Borrowings under Pre-Petition Credit Facilities	$ 2,965	2,965
Interest rate at period end	3.67%
Letters of credit outstanding	$ 80
Line of Credit | Revolving Credit Facility | PG&E Corporation
Debt [Line Items]
Debt subject to compromise	$ 300	300
Interest rate at period end	3.97%
Senior Notes | Pacific Gas & Electric Co
Debt [Line Items]
Unamortized discount, net or premium and debt issuance costs	$ 0	(178)
Long-term debt	17,525	17,347
Senior Notes | Senior Notes Due 2020 | Pacific Gas & Electric Co
Debt [Line Items]
Senior notes	800	800
Senior Notes | Senior Notes Due 2021 | Pacific Gas & Electric Co
Debt [Line Items]
Senior notes	$ 550	550
Senior Notes | Senior Notes Due 2021 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Contractual Interest Rates	3.25%
Senior Notes | Senior Notes Due 2021 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Contractual Interest Rates	4.25%
Senior Notes | Senior Notes Due 2022 | Pacific Gas & Electric Co
Debt [Line Items]
Senior notes	$ 400	400
Senior Notes | Senior Notes Due 2023 | Pacific Gas & Electric Co
Debt [Line Items]
Senior notes	$ 1,175	1,175
Senior Notes | Senior Notes Due 2023 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Contractual Interest Rates	3.25%
Senior Notes | Senior Notes Due 2023 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Contractual Interest Rates	4.25%
Senior Notes | Senior Notes Due 2024 through 2046 | Pacific Gas & Electric Co
Debt [Line Items]
Senior notes	$ 14,600	$ 14,600
Senior Notes | Senior Notes Due 2024 through 2046 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Contractual Interest Rates	2.95%
Senior Notes | Senior Notes Due 2024 through 2046 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Contractual Interest Rates	6.35%
Letter of Credit | Pollution Control Bonds Series 2009, A-B, Variable Rate, Due 2026 | Pacific Gas & Electric Co
Debt [Line Items]
Interest rate at period end	4.13%
Letter of Credit | Pollution Control Bonds, Series 1996 C,E,F 1997 B, Variable Rates, Due 2026 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Interest rate at period end	4.13%
Letter of Credit | Pollution Control Bonds, Series 1996 C,E,F 1997 B, Variable Rates, Due 2026 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Interest rate at period end	4.47%

EQUITY (Changes in Equity) (Det

EQUITY (Changes in Equity) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)	520,338,710
Beginning balance	$ 12,903	$ 19,472
Net income (loss)	136	445
Comprehensive income (loss)	136	445
Common stock issued, net	85	35
Stock-based compensation amortization	5	34
Preferred stock dividend requirement of subsidiary	$ (3)	(3)
Ending balance (in shares)	529,210,278
Ending balance	$ 13,129	19,983
Pacific Gas & Electric Co
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)	264,374,809
Comprehensive income (loss)	$ 133	452
Ending balance (in shares)	264,374,809
Total Shareholders’ Equity
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	$ 12,651	19,220
Net income (loss)	136	445
Common stock issued, net	85	35
Stock-based compensation amortization	5	34
Preferred stock dividend requirement of subsidiary		(3)
Ending balance	12,877	19,731
Total Shareholders’ Equity | Pacific Gas & Electric Co
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	12,955	19,747
Net income (loss)	133	452
Preferred stock dividend		(3)
Ending balance	13,088	20,196
Preferred Stock | Pacific Gas & Electric Co
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	258	258
Ending balance	$ 258	$ 258
Common Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)	520,338,710	514,775,845
Beginning balance	$ 12,910	$ 12,632
Common stock issued, net (in shares)	8,871,568	1,248,112
Common stock issued, net	$ 85	$ 35
Stock-based compensation amortization	$ 5	$ 34
Ending balance (in shares)	529,210,278	516,023,957
Ending balance	$ 13,000	$ 12,701
Common Stock | Pacific Gas & Electric Co
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	1,322	1,322
Ending balance	1,322	1,322
Additional Paid-in Capital | Pacific Gas & Electric Co
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	8,550	8,505
Ending balance	8,550	8,505
Reinvested Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	(250)	6,596
Net income (loss)	136	445
Preferred stock dividend requirement of subsidiary		(3)
Ending balance	(114)	7,038
Reinvested Earnings | Pacific Gas & Electric Co
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	2,826	9,656
Net income (loss)	133	452
Comprehensive income (loss)		2
Preferred stock dividend		(3)
Ending balance	2,959	10,107
Accumulated Other Comprehensive Income (Loss)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	(9)	(8)
Ending balance	(9)	(8)
Accumulated Other Comprehensive Income (Loss) | Pacific Gas & Electric Co
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	(1)	6
Comprehensive income (loss)		(2)
Ending balance	(1)	4
Non controlling Interest - Preferred Stock of Subsidiary
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	252	252
Ending balance	$ 252	$ 252

EQUITY (Narrative) (Details)

EQUITY (Narrative) (Details) - 401K Plan and Shared Based Compensation Plans shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)shares
Schedule Of Changes In Equity [Line Items]
Stock issued during period (in shares) | shares	8.9
Proceeds from stock issuance | $	$ 85

EARNINGS PER SHARE (Reconciliat

EARNINGS PER SHARE (Reconciliation of PG&E Corporation's Income Available for Common Shareholders and Weighted Average Common Shares Outstanding for Calculating Diluted EPS) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Earnings Per Share [Abstract]
Income available for common shareholders	$ 136	$ 445
Preferred stock dividend requirement of subsidiary	3	3
Adjusted income available for common shareholders	$ 133	$ 442
Weighted average common shares outstanding, basic (in shares)	526	515
Add incremental shares from assumed conversions:
Employee share-based compensation (in shares)	1	1
Weighted average common shares outstanding, diluted (in shares)	527	516
Total earnings per common share, diluted (in dollars per share)	$ 0.25	$ 0.86

DERIVATIVES (Volumes of Outstan

DERIVATIVES (Volumes of Outstanding Derivative Contracts, in Megawatt Hours Unless Otherwise Specified) (Details)	Mar. 31, 2019MWhMMBTU	Dec. 31, 2018MWhMMBTU
Forwards, Futures and Swaps | Natural gas
Derivative [Line Items]
Contract Volume | MMBTU	138,016,980	177,750,349
Forwards, Futures and Swaps | Electric
Derivative [Line Items]
Contract Volume | MWh	3,011,826	3,833,490
Options | Natural gas
Derivative [Line Items]
Contract Volume | MMBTU	4,115,000	13,735,405
Congestion Revenue Rights | Electric
Derivative [Line Items]
Contract Volume | MWh	335,556,726	340,783,089

FAIR VALUE MEASUREMENTS (Assets

FAIR VALUE MEASUREMENTS (Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Assets:
Short-term investments	$ 2,898	$ 1,593
Price risk management instruments, netting	37	88
Derivative Asset	247	297
TOTAL ASSETS	6,864	5,350
Liabilities:
Price risk management instruments, netting	(4)	(10)
TOTAL LIABILITIES	82	109
Amount primarily related to deferred taxes on appreciation of investment value	468	408
Nuclear decommissioning trusts
Assets:
Short-term investments	18	29
Global equity securities	1,882	1,793
Fixed-income securities	1,482	1,300
TOTAL ASSETS	3,400	3,138
Rabbi trusts
Assets:
Fixed-income securities	96	93
Life insurance contracts	69	67
TOTAL ASSETS	165	160
Long-term disability trust
Assets:
Short-term investments	8	7
TOTAL ASSETS	154	162
Price Risk Derivative, Electricity
Assets:
Price risk management instruments, netting	15	51
Derivative Asset	225	259
Liabilities:
Price risk management instruments, netting	(4)	(10)
Derivative Liability	80	107
Price Risk Derivative, Gas
Assets:
Price risk management instruments, netting	22	37
Derivative Asset	22	38
Liabilities:
Price risk management instruments, netting	0	0
Derivative Liability	2	2
Level 1
Assets:
Short-term investments	2,898	1,593
Price risk management instruments, gross subject to netting	0	0
TOTAL ASSETS	5,596	4,083
Liabilities:
TOTAL LIABILITIES	1	4
Level 1 | Nuclear decommissioning trusts
Assets:
Short-term investments	18	29
Global equity securities	1,882	1,793
Fixed-income securities	790	661
TOTAL ASSETS	2,690	2,483
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	8	7
TOTAL ASSETS	8	7
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	1	4
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	1	6
TOTAL ASSETS	858	805
Liabilities:
TOTAL LIABILITIES	5	7
Level 2 | Nuclear decommissioning trusts
Assets:
Short-term investments	0	0
Global equity securities	0	0
Fixed-income securities	692	639
TOTAL ASSETS	692	639
Level 2 | Rabbi trusts
Assets:
Fixed-income securities	96	93
Life insurance contracts	69	67
TOTAL ASSETS	165	160
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	1	5
Liabilities:
Price risk management instruments, gross subject to netting	3	5
Level 2 | Price Risk Derivative, Gas
Assets:
Price risk management instruments, gross subject to netting	0	1
Liabilities:
Price risk management instruments, gross subject to netting	2	2
Level 3
Assets:
Short-term investments	0	0
Price risk management instruments, gross subject to netting	209	203
TOTAL ASSETS	209	203
Liabilities:
TOTAL LIABILITIES	80	108
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	209	203
Liabilities:
Price risk management instruments, gross subject to netting	80	108
Level 3 | Price Risk Derivative, Gas
Assets:
Price risk management instruments, gross subject to netting	0	0
Liabilities:
Price risk management instruments, gross subject to netting	0	0
Fair Value Measured at Net Asset Value | Nuclear decommissioning trusts
Assets:
Assets measured at NAV	18	16
Fair Value Measured at Net Asset Value | Long-term disability trust
Assets:
Assets measured at NAV	$ 146	$ 155

DERIVATIVES (Outstanding Deriva

DERIVATIVES (Outstanding Derivative Balances) (Details) - Commodity Risk - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	$ 124	$ 90
Derivative Asset, Netting	0	0
Cash Collateral	41	98
Total Derivative Balance, Assets	165	188
Current assets – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	45	44
Derivative Asset, Netting	(2)	(1)
Cash Collateral	38	89
Total Derivative Balance, Assets	81	132
Other noncurrent assets – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	165	165
Derivative Asset, Netting	1	0
Cash Collateral	0	0
Total Derivative Balance, Assets	166	165
Current liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Liabilities	(37)	(29)
Derivative Liability, Netting	17	1
Cash Collateral	3	7
Total Derivative Balance, Liabilities	(17)	(21)
Noncurrent liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Liabilities	(49)	(90)
Derivative Liability, Netting	(16)	0
Cash Collateral	0	2
Total Derivative Balance, Liabilities	$ (65)	$ (88)

FAIR VALUE MEASUREMENTS (Level

FAIR VALUE MEASUREMENTS (Level 3 Measurements and Sensitivity Analysis) (Details) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2019USD ($)$ / MWh	Dec. 31, 2018USD ($)$ / MWh
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value	$ 6,864	$ 5,350
Liabilities, Fair Value	$ 82	$ 109
Congestion revenue rights | Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range | $ / MWh	(36.87)	(18.61)
Congestion revenue rights | Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range | $ / MWh	23.04	32.26
Power purchase agreements | Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range | $ / MWh	19.81	19.81
Power purchase agreements | Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range | $ / MWh	38.80	38.80
Market approach | Congestion revenue rights
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value	$ 203	$ 203
Liabilities, Fair Value	60	75
Discounted cash flow | Power purchase agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value	6	0
Liabilities, Fair Value	$ 20	$ 33

DERIVATIVES (Narrative) (Detail

DERIVATIVES (Narrative) (Details) $ in Millions	Mar. 31, 2019USD ($)
Pacific Gas & Electric Co
Derivative [Line Items]
Collateral posted for net liability derivative positions	$ 7

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, 2019	Mar. 31, 2018
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning asset (liability) balance	$ 95	$ 42
Net realized and unrealized gains: Included in regulatory assets and liabilities or balancing accounts	34	(2)
Ending asset (liability) balance	$ 129	$ 40

FAIR VALUE MEASUREMENTS (Carryi

FAIR VALUE MEASUREMENTS (Carrying Amount and Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions	Feb. 01, 2019	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Proceeds from debtor-in-possession credit facility	$ 350	$ 350	$ 0
Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument		0		$ 350
Pacific Gas & Electric Co
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument		3,215		3,215
Proceeds from debtor-in-possession credit facility		350	$ 0
Pacific Gas & Electric Co | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument		350		14,747
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument		0		350
Carrying Amount | Pacific Gas & Electric Co
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument		$ 350		$ 17,450

FAIR VALUE MEASUREMENTS (Schedu

FAIR VALUE MEASUREMENTS (Schedule of Unrealized Gains (Losses) Related to Available-for-Sale Investments) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	$ 1,931	$ 1,885
Total Unrealized Gains	1,480	1,276
Total Unrealized Losses	(11)	(23)
Total Fair Value	3,400	3,138
Amount primarily related to deferred taxes on appreciation of investment value	468	408
Short-term investments
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	18	29
Total Unrealized Gains	0	0
Total Unrealized Losses	0	0
Total Fair Value	18	29
Global equity securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	481	568
Total Unrealized Gains	1,422	1,246
Total Unrealized Losses	(3)	(5)
Total Fair Value	1,900	1,809
Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	1,432	1,288
Total Unrealized Gains	58	30
Total Unrealized Losses	(8)	(18)
Total Fair Value	$ 1,482	$ 1,300

FAIR VALUE MEASUREMENTS (Sche_2

FAIR VALUE MEASUREMENTS (Schedule of Maturities on Debt Securities) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Total maturities of fixed-income securities	$ 3,400	$ 3,138
Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Less than 1 year	31
1–5 years	534
5–10 years	337
More than 10 years	580
Total maturities of fixed-income securities	$ 1,482	$ 1,300

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, 2019	Mar. 31, 2018
Fair Value Disclosures [Abstract]
Proceeds from sales and maturities of nuclear decommissioning trust investments	$ 346	$ 494
Gross realized gains on securities	(34)	37
Gross realized losses on securities	$ 19	$ (4)

WILDFIRE-RELATED CONTINGENCIE_2

WILDFIRE-RELATED CONTINGENCIES (Wildfire-Related Claims Narrative) (Details) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Loss Contingencies [Line Items]
Reimbursements	$ (25,000,000)	$ (197,000,000)
Loss from Wildfires
Loss Contingencies [Line Items]
Reimbursements	0	(7,000,000)
2018 Camp fire
Loss Contingencies [Line Items]
Reimbursements	0
2017 Northern California wildfires
Loss Contingencies [Line Items]
Reimbursements	0
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Reimbursements	(25,000,000)	$ (197,000,000)
Pacific Gas & Electric Co | 2018 Camp fire
Loss Contingencies [Line Items]
Legal and other costs	13,000,000
Pacific Gas & Electric Co | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Legal and other costs	$ 34,000,000

WILDFIRE-RELATED CONTINGENCIE_3

WILDFIRE-RELATED CONTINGENCIES (Summary of Estimated Liabilities) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Loss Contingencies [Line Items]
Total wildfire-related claims	$ 0	$ 14,226
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Total wildfire-related claims	14,212	14,226
Pacific Gas & Electric Co | 2015 Butte fire
Loss Contingencies [Line Items]
Total wildfire-related claims	212	226
Pacific Gas & Electric Co | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Total wildfire-related claims	3,500	3,500
Pacific Gas & Electric Co | 2018 Camp fire
Loss Contingencies [Line Items]
Total wildfire-related claims	$ 10,500	$ 10,500

WILDFIRE-RELATED CONTINGENCIE_4

WILDFIRE-RELATED CONTINGENCIES (2018 Camp Fire Background) (Details) - Pacific Gas & Electric Co - 2018 Camp fire	Dec. 11, 2018	Nov. 16, 2018report	Nov. 16, 2018report	Nov. 08, 2018report	Feb. 07, 2019fatality	Jan. 04, 2019aresidencefatalitystructure
Loss Contingencies [Line Items]
Number of acres burned (acre) | a						153,336
Number of fatalities (fatality)					85	86
Number of residences destroyed (residence) | residence						13,972
Number of commercial structures destroyed (structure) | structure						528
Number of other buildings destroyed (building)						4,293
Number of Electric Incident Reports (report) | report		1	2	1
Electric Incident Report, term	20 days

WILDFIRE-RELATED CONTINGENCIE_5

WILDFIRE-RELATED CONTINGENCIES (2017 Northern California Wildfires Background) (Details) - Pacific Gas & Electric Co - 2017 Northern California wildfires a in Thousands, $ in Thousands	Mar. 31, 2019USD ($)wildfireincident_report	Jan. 04, 2019wildfire	Jun. 30, 2018wildfire	Oct. 30, 2017awildfirefatalitystructure
Loss Contingencies [Line Items]
Number of wildfires (wildfire)		18		21
Number of acres burned (acre) | a				245
Number of structures destroyed (structure) | structure				8,900
Number of fatalities (fatality) | fatality				44
Number of fires in which determination has been reported on (wildfire)	19		16
Number of electric incident reports submitted (incident report) | incident_report	23
Property damage coverage per incident | $	$ 50

WILDFIRE-RELATED CONTINGENCIE_6

WILDFIRE-RELATED CONTINGENCIES (Third-Party Claims, Investigations and Other Proceedings Related to the 2018 Camp Fire and 2017 Northern California Wildfires) (Details) - Pending Litigation	Jan. 28, 2019wildfirecomplaintplaintiff
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)	100
Number of plaintiffs in lawsuit (at least) (plaintiff) | plaintiff	4,200
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) | wildfire	9
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)	750
Number of plaintiffs in lawsuit (at least) (plaintiff) | plaintiff	3,800
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) | wildfire	5
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)	52
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)	39

WILDFIRE-RELATED CONTINGENCIE_7

WILDFIRE-RELATED CONTINGENCIES (Potential Losses in Connection with the 2018 Camp Fire and 2017 Northern California Wildfires) (Details) insurance_claim in Thousands, $ in Millions	Jan. 28, 2019USD ($)	Sep. 06, 2018USD ($)insurance_claim	Dec. 31, 2018USD ($)	Dec. 31, 2015USD ($)	Mar. 31, 2019USD ($)
November 2018 Fires
Loss Contingencies [Line Items]
Total insurance claims received by insurers (more than)	$ 11,400
2018 Camp fire
Loss Contingencies [Line Items]
Total insurance claims received by insurers (more than)	8,400
Loss in period			$ 10,500
2017 Northern California wildfires
Loss Contingencies [Line Items]
Total insurance claims received by insurers (more than)		$ 12,280
Insurance claims received by insurers (insurance claim) | insurance_claim		55
Statewide insurance claims related to wildfire		$ 10,000
2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Total insurance claims received by insurers (more than)	$ 18,400
Estimate of possible losses					$ 30,000
Pacific Gas & Electric Co | San Bruno Natural Gas Explosion
Loss Contingencies [Line Items]
Loss in period				$ 1,600
Loss contingency liability				$ 558

WILDFIRE-RELATED CONTINGENCIE_8

WILDFIRE-RELATED CONTINGENCIES (2018 Camp Fire and 2017 Northern California Wildfires Accounting Charge) (Details) $ in Billions	Dec. 11, 2018	Dec. 31, 2018USD ($)	Jun. 30, 2018USD ($)	Dec. 31, 2018USD ($)	Mar. 31, 2019wildfire
2018 Camp fire
Loss Contingencies [Line Items]
Accrued losses				$ 10.5
2017 Northern California wildfires
Loss Contingencies [Line Items]
Number of fires with probable losses (wildfire) | wildfire					17
Loss from claims related to wildfire		$ 1	$ 2.5	$ 3.5
Pacific Gas & Electric Co | 2018 Camp fire
Loss Contingencies [Line Items]
Electric Incident Report, term	20 days

WILDFIRE-RELATED CONTINGENCIE_9

WILDFIRE-RELATED CONTINGENCIES (Loss Recoveries) (Details)	Apr. 05, 2019USD ($)concept	Mar. 31, 2019USD ($)	Feb. 11, 2019USD ($)	Sep. 30, 2018USD ($)	Jul. 31, 2018USD ($)
2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Liability insurance coverage				$ 1,400,000,000	$ 842,000,000
Initial self-insured retention per occurrence				10,000,000	10,000,000
Further retention per occurrence					$ 40,000,000
Liability insurance coverage, general liability				700,000,000
Liability insurance coverage, property damages				700,000,000
Liability insurance coverage, property damages, reinsurance				$ 200,000,000
Estimated additional borrowings as part of reorganization			$ 3,000,000,000
2018 Camp fire
Loss Contingencies [Line Items]
Estimated insurance recoveries		$ 1,380,000,000
2017 Northern California wildfires
Loss Contingencies [Line Items]
Estimated insurance recoveries		$ 842,000,000
Subsequent Event | 2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Customer Harm Threshold, potential regulatory adjustment, percentage	20.00%
Customer Harm Threshold, potential regulatory adjustment, percentage of total disallowed wildlife liability	5.00%
Customer Harm Threshold, number of proposed optional concepts for ratepayer protection | concept	2
Customer Harm Threshold, maximum de-escalation of authorized return on equity	3.00%
Customer Harm Threshold, customer equity warrants, percentage of securitized wildlife liability	1.00%
Customer Harm Threshold, increment of securitized wildlife liability	$ 500,000,000
Subsequent Event | Maximum | 2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Customer Harm Threshold, customer equity warrants, percentage of securitized wildlife liability	15.00%

WILDFIRE-RELATED CONTINGENCI_10

WILDFIRE-RELATED CONTINGENCIES (Summary of Insurance Receivables) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Insurance Receivable [Roll Forward]
Wildfire-related insurance receivable	$ 25	$ 197
2018 Camp fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	1,380
Accrued insurance recoveries	0
Wildfire-related insurance receivable	0
Insurance Receivable, Ending Balance	1,380
2017 Northern California wildfires
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	829
Accrued insurance recoveries	0
Wildfire-related insurance receivable	0
Insurance Receivable, Ending Balance	$ 829

WILDFIRE-RELATED CONTINGENCI_11

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_12

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	Jun. 30, 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_13

WILDFIRE-RELATED CONTINGENCIES (District Attorneys’ Offices’ Investigations) (Details) - Pacific Gas & Electric Co - Complaints Brought By Butte County District Attorney - Loss from Wildfires $ in Millions	1 Months Ended
	Oct. 31, 2018USD ($)wildfire
Loss Contingencies [Line Items]
Number of wildfires (wildfire) | wildfire	2
Settlement agreement term	4 years
Settlement expense | $	$ 1.5

WILDFIRE-RELATED CONTINGENCI_14

WILDFIRE-RELATED CONTINGENCIES (Clean-up and Repair Costs) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Loss Contingencies [Line Items]
Capital expenditures	$ 242	$ 255
Total long-term regulatory assets	5,151		$ 4,964
Catastrophic event memorandum account
Loss Contingencies [Line Items]
Total long-term regulatory assets	865		790
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Capital expenditures	242	$ 255
Total long-term regulatory assets	5,151		$ 4,964
Pacific Gas & Electric Co | 2018 Camp fire
Loss Contingencies [Line Items]
Service restoration and repair costs	559
Capital expenditures	204
Pacific Gas & Electric Co | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Service restoration and repair costs	330
Capital expenditures	157
Pacific Gas & Electric Co | Catastrophic event memorandum account | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Total long-term regulatory assets	$ 132

WILDFIRE-RELATED CONTINGENCI_15

WILDFIRE-RELATED CONTINGENCIES (Proposed Wildfire Assistance Fund) (Details) - USD ($) $ in Millions	May 01, 2019	Mar. 31, 2019	Dec. 31, 2018
Loss Contingencies [Line Items]
Wildfire-related claims		$ 0	$ 14,226
Subsequent Event | 2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Wildfire Assistance Fund, amount sought	$ 105
Wildfire Assistance Fund, amount sought, portion available for administrative expenses	$ 5
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Wildfire-related claims		14,212	$ 14,226
Pacific Gas & Electric Co | 2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Wildfire-related claims		$ 14,000

WILDFIRE-RELATED CONTINGENCI_16

WILDFIRE-RELATED CONTINGENCIES (2015 Butte Fire) (Details) - Pacific Gas & Electric Co - 2015 Butte fire household in Thousands, $ in Millions

Jan. 28, 2019contractorhouseholdplaintiff

Nov. 13, 2018USD ($)

Sep. 06, 2018plaintiff

Mar. 02, 2018USD ($)

Mar. 01, 2018USD ($)

Apr. 13, 2017USD ($)

May 31, 2017USD ($)

Sep. 30, 2018plaintiff

Mar. 31, 2019USD ($)

May 01, 2018decision

May 23, 2016contractor

Apr. 28, 2016aoutbuildingfatalityhomecomercial_propertystructure

Loss Contingencies [Line Items]

Number of acres burned (acre) | a

70,868

Number of fatalities caused by fire (fatality) | fatality

2

Number of homes destroyed by fire (home) | home

549

Number of outbuildings damaged by fire (outbuilding) | outbuilding

368

Number of commercial properties damaged by fire (commercial property) | comercial_property

4

Number of structures damaged (structure) | structure

44

Number of vegetation management contractors (contractor) | contractor

2

Number of complaints filed (complaint) | contractor

95

Number of plaintiffs (plaintiff) | plaintiff

3,900

Number of households represented in court (household) | household

2

Number of vegetation management contractors dismissed from complaints (contractor) | contractor

2

Number of plaintiffs, smaller public entities (plaintiff) | plaintiff

5

Number of plaintiffs, fire districts (plaintiff) | plaintiff

3

Number of plaintiffs, water district (plaintiff) | plaintiff

1

Fire fighting costs recovery requested

$ 87

Value of claims brought against the company

$ 190

Reasonably possible loss to be incurred

$ 1,100

Coverage for third party liability

922

Probable insurance recoveries

922

Cumulative reimbursements from insurance policies

$ 60

Agreement Reached in Litigation to Stipulate to Judgment on Inverse Condemnation Grounds

Loss Contingencies [Line Items]

Number of previous appellate courts decisions (decision) | decision

2

Number of plaintiffs in lawsuit (plaintiff) | plaintiff

2

County of Calaveras

Loss Contingencies [Line Items]

Value of claims brought against company

$ 167

$ 85

Settlement reached

$ 25.4

Settled Litigation

Loss Contingencies [Line Items]

Number of plaintiffs, fire districts (plaintiff) | plaintiff

3

WILDFIRE-RELATED CONTINGENCI_17

WILDFIRE-RELATED CONTINGENCIES (Schedule of Loss Accrual) (Details) - 2015 Butte fire - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Loss Contingency Accrual [Roll Forward]
Loss accrual, beginning balance	$ 226	$ 561	$ 690	$ 0
Accrued losses	0	0	350	750
Payments	(14)	(335)	(479)	(60)
Loss accrual, ending balance	212	$ 226	$ 561	$ 690
Pacific Gas & Electric Co
Loss Contingency Accrual [Roll Forward]
Settlement agreement paid	888
Settlement agreements entered	$ 904

WILDFIRE-RELATED CONTINGENCI_18

WILDFIRE-RELATED CONTINGENCIES (Schedule of Insurance Receivable) (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Insurance Receivable [Roll Forward]
Wildfire-related insurance receivable	$ 25	$ 197
2015 Butte fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	85	$ 596	$ 596	$ 575	$ 0
Accrued insurance recoveries	0		0	297	625
Wildfire-related insurance receivable	25		511	276	50
Insurance Receivable, Ending Balance	$ 60		$ 85	$ 596	$ 575

OTHER CONTINGENCIES AND COMMI_3

OTHER CONTINGENCIES AND COMMITMENTS (Enforcement and Litigation Matters) (Details) - Pacific Gas & Electric Co $ in Millions	Jan. 26, 2017USD ($)	Jan. 04, 2019wildfire	Oct. 30, 2017wildfire	Aug. 09, 2016count
2017 Northern California wildfires
Loss Contingencies [Line Items]
Number of wildfires (wildfire) | wildfire		18	21
Judicial Ruling | Unfavorable Regulatory Action
Loss Contingencies [Line Items]
Number of guilty counts of obstructing a federal agency proceeding				1
Number of guilty counts of violating pipeline integrity management regulations				5
Corporate probation period, term	5 years
Oversight by third-party monitor period, application for early termination, term	3 years
Damages awarded, value | $	$ 3

OTHER CONTINGENCIES AND COMMI_4

OTHER CONTINGENCIES AND COMMITMENTS (CPUC and FERC Matters) (Details) $ in Thousands	Mar. 31, 2019USD ($)	Sep. 21, 2018	May 17, 2018USD ($)	Apr. 26, 2018USD ($)	Dec. 06, 2018consultant
Ex Parte Communications
Loss Contingencies [Line Items]
Proposed penalty				$ 97,500
Payment to State General Fund			$ 12,000	12,000
Gas transmission and storage revenue reduction				63,500
2018 GTandS revenue requirement reduction				31,750
2019 GTandS revenue requirement reduction				31,750
Revenue requirement reduction in Next GRC cycle				10,000
Payment to city of San Bruno			6,000	6,000
Payment to city of San Carlos			$ 6,000	$ 6,000
Disallowance of Plant Costs
Loss Contingencies [Line Items]
Accrual for GTandS revenue requirement reduction	$ 8,000
Pacific Gas & Electric Co | Pending Litigation | Unfavorable Regulatory Action
Loss Contingencies [Line Items]
Number of consultants retained | consultant					2
Electric | Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Requested revenue rate		98.85%

OTHER CONTINGENCIES AND COMMI_5

OTHER CONTINGENCIES AND COMMITMENTS (Other Matters) (Details) - USD ($) $ in Millions	Jun. 23, 2016	Dec. 31, 2018
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Accrued legal liabilities		$ 98
Disallowance of Plant Costs
Loss Contingencies [Line Items]
Gas transmission and storage capital disallowance	$ 696
Permanently disallowed capital	120
Amount subject to audit	$ 576

OTHER CONTINGENCIES AND COMMI_6

OTHER CONTINGENCIES AND COMMITMENTS (Schedule of Environmental Remediation Liability Composed) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Disclosure Commitments And Contingencies Environmental Remediation Liability Composed [Abstract]
Topock natural gas compressor station	$ 358	$ 369
Hinkley natural gas compressor station	145	146
Former manufactured gas plant sites owned by the Utility or third parties	525	520
Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites	107	111
Fossil fuel-fired generation facilities and sites	131	137
Total environmental remediation liability	$ 1,266	$ 1,283

OTHER CONTINGENCIES AND COMMI_7

OTHER CONTINGENCIES AND COMMITMENTS (Environmental Remediation Contingencies Narrative) (Details) $ in Millions	Mar. 31, 2019USD ($)
Long-term Purchase Commitment [Line Items]
Amount of environmental loss accrual expected to be recovered	$ 920
Topock Site
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 303
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]
Utility undiscounted future costs	$ 142
Former Manufactured Gas Plant
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 514
Remediation cost recovery percentage	90.00%
Utility Owned Generation Facilities and Third Party Disposal Sites
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 132
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]
Utility undiscounted future costs	$ 91

OTHER CONTINGENCIES AND COMMI_8

OTHER CONTINGENCIES AND COMMITMENTS (Wildfire Insurance) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Loss Contingencies [Line Items]
Costs for insurance coverage	$ 360
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Costs for insurance coverage	50
Insurance Coverage for Wildfire Events
Loss Contingencies [Line Items]
Liability insurance coverage		$ 1,400
Insurance Coverage for Wildfire Liabilities
Loss Contingencies [Line Items]
Liability insurance coverage		700
Catastrophic bond reinsurance instrument		10
Insurance Coverage for Property Damages
Loss Contingencies [Line Items]
Liability insurance coverage		700
Catastrophic bond reinsurance instrument		$ 200
2018 Camp fire
Loss Contingencies [Line Items]
Estimated insurance recoveries	1,380
2017 Northern California wildfires
Loss Contingencies [Line Items]
Estimated insurance recoveries	$ 842

OTHER CONTINGENCIES AND COMMI_9

OTHER CONTINGENCIES AND COMMITMENTS (Nuclear Insurance) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)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	$ 44
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_10

OTHER CONTINGENCIES AND COMMITMENTS (Tax Matters) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)
Pacific Gas & Electric Co
Disaggregation of Revenue [Line Items]
Unrecognized tax benefits, decrease resulting from settlements with taxing authorities	$ 10

OTHER CONTINGENCIES AND COMM_11

OTHER CONTINGENCIES AND COMMITMENTS (Purchase Commitments) (Details) $ in Billions	Dec. 31, 2018USD ($)
Commitments and Contingencies Disclosure [Abstract]
Recorded unconditional purchase obligation	$ 40