PG&E (PCG) 10-Q 9 Aug 19 2019 Q2 Quarterly report Financial data

Cover Page

Cover Page - shares	6 Months Ended
	Jun. 30, 2019	Aug. 02, 2019
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2019
Document Transition Report	false
Entity File Number	1-12609
Entity Registrant Name	PG&E CORP
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	94-3234914
Entity Address, Address Line One	77 Beale Street
Entity Address, Address Line Two	P.O. Box 770000
Entity Address, City or Town	San Francisco,
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	94177
City Area Code	415
Local Phone Number	973-1000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)		529,223,793
Amendment Flag	false
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2
Entity Central Index Key	0001004980
Pacific Gas & Electric Co
Entity Information [Line Items]
Entity File Number	1-2348
Entity Registrant Name	PACIFIC GAS & ELECTRIC CO
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	94-0742640
Entity Address, Address Line One	77 Beale Street
Entity Address, Address Line Two	P.O. Box 770000
Entity Address, City or Town	San Francisco,
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	94177
City Area Code	415
Local Phone Number	973-7000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)		264,374,809
Entity Central Index Key	0000075488
The New York Stock Exchange | Common stock, no par value
Entity Information [Line Items]
Title of 12(b) Security	Common stock, no par value
Trading Symbol	PCG
Security Exchange Name	NYSE
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 5% series A redeemable
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 5% series A redeemable
Trading Symbol	PCG-PE
Security Exchange Name	NYSEAMER
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 5% redeemable
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 5% redeemable
Trading Symbol	PCG-PD
Security Exchange Name	NYSEAMER
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 4.80% redeemable
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 4.80% redeemable
Trading Symbol	PCG-PG
Security Exchange Name	NYSEAMER
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 4.50% redeemable
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 4.50% redeemable
Trading Symbol	PCG-PH
Security Exchange Name	NYSEAMER
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 4.36% series A redeemable
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 4.36% series A redeemable
Trading Symbol	PCG-PI
Security Exchange Name	NYSEAMER
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 6% nonredeemable
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 6% nonredeemable
Trading Symbol	PCG-PA
Security Exchange Name	NYSEAMER
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 5.50% nonredeemable
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 5.50% nonredeemable
Trading Symbol	PCG-PB
Security Exchange Name	NYSEAMER
NYSE American LLC | First preferred stock, cumulative, par value $25 per share, 5% nonredeemable
Entity Information [Line Items]
Title of 12(b) Security	First preferred stock, cumulative, par value $25 per share, 5% nonredeemable
Trading Symbol	PCG-PC
Security Exchange Name	NYSEAMER

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Operating Revenues
Total operating revenues	$ 3,943	$ 4,234	$ 7,954	$ 8,290
Operating Expenses
Operating and maintenance	1,942	1,786	4,029	3,390
Wildfire-related claims, net of insurance recoveries	3,900	2,125	3,900	2,118
Depreciation, amortization, and decommissioning	796	746	1,593	1,498
Total operating expenses	7,583	5,699	11,405	9,156
Operating Loss	(3,640)	(1,465)	(3,451)	(866)
Interest income	22	12	44	21
Interest expense	(60)	(226)	(163)	(446)
Other income, net	66	106	137	214
Reorganization items, net	(56)	0	(183)	0
Loss Before Income Taxes	(3,668)	(1,573)	(3,616)	(1,077)
Income tax benefit	(1,119)	(593)	(1,203)	(542)
Net Loss	(2,549)	(980)	(2,413)	(535)
Preferred stock dividend requirement of subsidiary	4	4	7	7
Loss Attributable to Common Shareholders	$ (2,553)	$ (984)	$ (2,420)	$ (542)
Weighted Average Common Shares Outstanding, Basic (in shares)	529	516	528	516
Weighted Average Common Shares Outstanding, Diluted (in shares)	529	516	528	517
Net Loss Per Common Share, Basic (in dollars per share)	$ (4.83)	$ (1.91)	$ (4.58)	$ (1.05)
Net Loss Per Common Share, Diluted (in dollars per share)	$ (4.83)	$ (1.91)	$ (4.58)	$ (1.05)
Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	$ 3,943	$ 4,234	$ 7,954	$ 8,290
Operating Expenses
Operating and maintenance	1,940	1,786	4,044	3,390
Wildfire-related claims, net of insurance recoveries	3,900	2,125	3,900	2,118
Depreciation, amortization, and decommissioning	796	746	1,593	1,498
Total operating expenses	7,581	5,699	11,420	9,156
Operating Loss	(3,638)	(1,465)	(3,466)	(866)
Interest income	22	11	43	20
Interest expense	(60)	(222)	(161)	(439)
Other income, net	64	108	130	217
Reorganization items, net	(57)	0	(168)	0
Loss Before Income Taxes	(3,669)	(1,568)	(3,622)	(1,068)
Income tax benefit	(1,119)	(592)	(1,205)	(544)
Net Loss	(2,550)	(976)	(2,417)	(524)
Preferred stock dividend requirement of subsidiary	4	4	7	7
Loss Attributable to Common Shareholders	(2,554)	(980)	(2,424)	(531)
Electric
Operating Revenues
Total operating revenues	2,946	3,312	5,738	6,263
Operating Expenses
Cost of goods	837	963	1,436	1,782
Electric | Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	2,946	3,312	5,738	6,263
Operating Expenses
Cost of goods	837	963	1,436	1,782
Natural gas
Operating Revenues
Total operating revenues	997	922	2,216	2,027
Operating Expenses
Cost of goods	108	79	447	368
Natural gas | Pacific Gas & Electric Co
Operating Revenues
Total operating revenues	997	922	2,216	2,027
Operating Expenses
Cost of goods	$ 108	$ 79	$ 447	$ 368

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Net Loss	$ (2,549)	$ (980)	$ (2,413)	$ (535)
Other Comprehensive Income
Pension and other post-retirement benefit plans obligations (net of taxes)	0	0	0	0
Total other comprehensive income	0	0	0	0
Comprehensive Loss	(2,549)	(980)	(2,413)	(535)
Preferred stock dividend requirement of subsidiary	4	4	7	7
Comprehensive Loss Attributable to Common Shareholders	(2,553)	(984)	(2,420)	(542)
Pacific Gas & Electric Co
Net Loss	(2,550)	(976)	(2,417)	(524)
Other Comprehensive Income
Pension and other post-retirement benefit plans obligations (net of taxes)	0	1	0	1
Total other comprehensive income	0	1	0	1
Comprehensive Loss	$ (2,550)	$ (975)	$ (2,417)	$ (523)

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Pension and other postretirement benefit plans obligations tax	$ 0	$ 0	$ 0	$ 0
Pacific Gas & Electric Co
Pension and other postretirement benefit plans obligations tax	$ 0	$ 0	$ 0	$ 0

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Current Assets
Cash and cash equivalents	$ 3,459	$ 1,668
Accounts receivable:
Customers (net of allowance for doubtful accounts of $39 and $56 at respective dates)	1,260	1,148
Accrued unbilled revenue	991	1,000
Regulatory balancing accounts	1,884	1,435
Other	2,610	2,686
Regulatory assets	212	233
Inventories:
Gas stored underground and fuel oil	99	111
Materials and supplies	509	443
Income taxes receivable	18	23
Other	535	448
Total current assets	11,577	9,195
Property, Plant, and Equipment
Electric	60,967	59,150
Gas	22,428	21,556
Construction work in progress	2,563	2,564
Other	20	2
Total property, plant, and equipment	85,978	83,272
Accumulated depreciation	(25,727)	(24,715)
Net property, plant, and equipment	60,251	58,557
Other Noncurrent Assets
Regulatory assets	5,349	4,964
Nuclear decommissioning trusts	3,016	2,730
Operating lease right of use asset	2,662
Income taxes receivable	67	69
Other	1,465	1,480
Total other noncurrent assets	12,559	9,243
TOTAL ASSETS	84,387	76,995
Current Liabilities
Short-term borrowings	0	3,435
Long-term debt, classified as current	0	18,559
Accounts payable:
Trade creditors	1,679	1,975
Regulatory balancing accounts	1,370	1,076
Other	593	464
Operating lease liabilities	546
Disputed claims and customer refunds	0	220
Interest payable	5	228
Wildfire-related claims	100	14,226
Other	1,418	1,512
Total current liabilities	5,711	41,695
Noncurrent Liabilities
Debtor-in-possession financing	1,500	0
Regulatory liabilities	9,038	8,539
Pension and other post-retirement benefits	1,996	2,119
Asset retirement obligations	6,111	5,994
Deferred income taxes	2,354	3,281
Operating lease liabilities	2,116
Other	2,357	2,464
Total noncurrent liabilities	25,472	22,397
Liabilities Subject to Compromise	42,610	0
Shareholders’ Equity
Common stock	13,014	12,910
Reinvested earnings	(2,663)	(250)
Accumulated other comprehensive loss	(9)	(9)
Total shareholders’ equity	10,342	12,651
Noncontrolling Interest - Preferred Stock of Subsidiary	252	252
Total equity	10,594	12,903
TOTAL LIABILITIES AND EQUITY	84,387	76,995
Pacific Gas & Electric Co
Current Assets
Cash and cash equivalents	3,036	1,295
Accounts receivable:
Customers (net of allowance for doubtful accounts of $39 and $56 at respective dates)	1,260	1,148
Accrued unbilled revenue	991	1,000
Regulatory balancing accounts	1,884	1,435
Other	2,621	2,688
Regulatory assets	212	233
Inventories:
Gas stored underground and fuel oil	99	111
Materials and supplies	509	443
Income taxes receivable	1	5
Other	535	448
Total current assets	11,148	8,806
Property, Plant, and Equipment
Electric	60,967	59,150
Gas	22,428	21,556
Construction work in progress	2,563	2,564
Other	18	0
Total property, plant, and equipment	85,976	83,270
Accumulated depreciation	(25,725)	(24,713)
Net property, plant, and equipment	60,251	58,557
Other Noncurrent Assets
Regulatory assets	5,349	4,964
Nuclear decommissioning trusts	3,016	2,730
Operating lease right of use asset	2,653
Income taxes receivable	66	66
Other	1,325	1,348
Total other noncurrent assets	12,409	9,108
TOTAL ASSETS	83,808	76,471
Current Liabilities
Short-term borrowings	0	3,135
Long-term debt, classified as current	0	18,209
Accounts payable:
Trade creditors	1,678	1,972
Regulatory balancing accounts	1,370	1,076
Other	688	498
Operating lease liabilities	543
Disputed claims and customer refunds	0	220
Interest payable	5	227
Wildfire-related claims	100	14,226
Other	1,420	1,497
Total current liabilities	5,804	41,060
Noncurrent Liabilities
Debtor-in-possession financing	1,500	0
Regulatory liabilities	9,038	8,539
Pension and other post-retirement benefits	1,996	2,026
Asset retirement obligations	6,111	5,994
Deferred income taxes	2,474	3,405
Operating lease liabilities	2,110
Other	2,408	2,492
Total noncurrent liabilities	25,637	22,456
Liabilities Subject to Compromise	41,829	0
Shareholders’ Equity
Preferred stock	258	258
Common stock	1,322	1,322
Additional paid-in capital	8,550	8,550
Reinvested earnings	409	2,826
Accumulated other comprehensive loss	(1)	(1)
Total shareholders’ equity	10,538	12,955
TOTAL LIABILITIES AND EQUITY	$ 83,808	$ 76,471

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Allowance for doubtful accounts	$ 39	$ 56
Common stock, shares authorized (in shares)	800,000,000	800,000,000
Common stock, shares outstanding (in shares)	529,223,793	520,338,710
Pacific Gas & Electric Co
Allowance for doubtful accounts	$ 39	$ 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	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Cash Flows from Operating Activities
Net Loss	$ (2,413)	$ (535)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	1,593	1,498
Allowance for equity funds used during construction	(45)	(63)
Deferred income taxes and tax credits, net	(915)	(145)
Reorganization items, net (Note 2)	90	0
Other	53	104
Effect of changes in operating assets and liabilities:
Accounts receivable	(54)	(11)
Wildfire-related insurance receivable	35	(144)
Inventories	(41)	(6)
Accounts payable	159	39
Wildfire-related claims	(14)	2,299
Income taxes receivable/payable	5	0
Other current assets and liabilities	(15)	(103)
Regulatory assets, liabilities, and balancing accounts, net	(34)	(12)
Liabilities subject to compromise	4,221	0
Other noncurrent assets and liabilities	132	(168)
Net cash provided by operating activities	2,757	2,753
Cash Flows from Investing Activities
Capital expenditures	(2,410)	(2,897)
Proceeds from sales and maturities of nuclear decommissioning trust investments	517	802
Purchases of nuclear decommissioning trust investments	(547)	(815)
Other	6	15
Net cash used in investing activities	(2,434)	(2,895)
Cash Flows from Financing Activities
Proceeds from debtor-in-possession credit facility	1,850	0
Repayments of debtor-in-possession credit facility	(350)	0
Debtor-in-possession credit facility debt issuance costs	(111)	0
Borrowings under revolving credit facilities	0	700
Net repayments of commercial paper, net of discount	0	(182)
Short-term debt financing	0	250
Short-term debt matured	0	(250)
Proceeds from issuance of long-term debt, net of discount and issuance costs	0	350
Long-term debt matured or repurchased	0	(750)
Common stock issued	85	82
Other	(6)	10
Net cash provided by financing activities	1,468	210
Net change in cash, cash equivalents, and restricted cash	1,791	68
Cash, cash equivalents, and restricted cash at January 1	1,675	456
Cash, cash equivalents, and restricted cash at June 30	3,466	524
Less: Restricted cash and restricted cash equivalents included in other current assets	(7)	(7)
Cash and cash equivalents at June 30	3,459	517
Supplemental disclosures of cash flow information
Interest, net of amounts capitalized	(21)	(394)
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	836	317
Pacific Gas & Electric Co
Cash Flows from Operating Activities
Net Loss	(2,417)	(524)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and decommissioning	1,593	1,498
Allowance for equity funds used during construction	(45)	(63)
Deferred income taxes and tax credits, net	(920)	(149)
Reorganization items, net (Note 2)	91	0
Other	34	57
Effect of changes in operating assets and liabilities:
Accounts receivable	(64)	(11)
Wildfire-related insurance receivable	35	(144)
Inventories	(41)	(6)
Accounts payable	206	40
Wildfire-related claims	(14)	2,299
Income taxes receivable/payable	4	0
Other current assets and liabilities	(8)	(95)
Regulatory assets, liabilities, and balancing accounts, net	(34)	(12)
Liabilities subject to compromise	4,215	0
Other noncurrent assets and liabilities	141	(168)
Net cash provided by operating activities	2,776	2,722
Cash Flows from Investing Activities
Capital expenditures	(2,410)	(2,897)
Proceeds from sales and maturities of nuclear decommissioning trust investments	517	802
Purchases of nuclear decommissioning trust investments	(547)	(815)
Other	6	15
Net cash used in investing activities	(2,434)	(2,895)
Cash Flows from Financing Activities
Proceeds from debtor-in-possession credit facility	1,850	0
Repayments of debtor-in-possession credit facility	(350)	0
Debtor-in-possession credit facility debt issuance costs	(95)	0
Borrowings under revolving credit facilities	0	650
Net repayments of commercial paper, net of discount	0	(50)
Short-term debt financing	0	250
Short-term debt matured	0	(250)
Long-term debt matured or repurchased	0	(400)
Other	(6)	10
Net cash provided by financing activities	1,399	210
Net change in cash, cash equivalents, and restricted cash	1,741	37
Cash, cash equivalents, and restricted cash at January 1	1,302	454
Cash, cash equivalents, and restricted cash at June 30	3,043	491
Less: Restricted cash and restricted cash equivalents included in other current assets	(7)	(7)
Cash and cash equivalents at June 30	3,036	484
Supplemental disclosures of cash flow information
Interest, net of amounts capitalized	(19)	(387)
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	$ 836	$ 317

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) $ in Millions	6 Months Ended
	Jun. 30, 2018USD ($)
Statement of Cash Flows [Abstract]
Discount on net issuances of commercial paper	$ 1

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY - USD ($) $ in Millions	Total	Common Stock	Reinvested Earnings	Accumulated Other Comprehensive Income (Loss)	Total Shareholders’ Equity	Non controlling Interest - Preferred Stock of Subsidiary	Pacific Gas & Electric Co	Pacific Gas & Electric CoPreferred Stock	Pacific Gas & Electric CoCommon Stock	Pacific Gas & Electric CoAdditional Paid-in Capital	Pacific Gas & Electric CoReinvested Earnings	Pacific Gas & Electric CoAccumulated Other Comprehensive Income (Loss)	Pacific Gas & Electric CoTotal Shareholders’ Equity
Beginning balance (in shares) at Dec. 31, 2017		514,755,845
Beginning balance at Dec. 31, 2017	$ 19,472	$ 12,632	$ 6,596	$ (8)	$ 19,220	$ 252		$ 258	$ 1,322	$ 8,505	$ 9,656	$ 6	$ 19,747
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss											452		452
Other comprehensive income (loss)											2	(2)
Preferred stock dividend											(3)		(3)
Ending balance at Mar. 31, 2018								258	1,322	8,505	10,107	4	20,196
Beginning balance (in shares) at Dec. 31, 2017		514,755,845
Beginning balance at Dec. 31, 2017	19,472	$ 12,632	6,596	(8)	19,220	252		258	1,322	8,505	9,656	6	19,747
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	(535)						$ (524)
Ending balance (in shares) at Jun. 30, 2018		517,102,983
Ending balance at Jun. 30, 2018	19,061	$ 12,763	6,059	(13)	18,809	252		258	1,322	8,505	9,127	5	19,217
Beginning balance at Mar. 31, 2018								258	1,322	8,505	10,107	4	20,196
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	(980)		(980)		(980)		$ (976)				(976)		(976)
Other comprehensive income (loss)	0			0	0							1	1
Common stock issued, net (in shares)		1,099,026
Common stock issued, net	47	$ 47			47
Stock-based compensation amortization	15	$ 15			15
Preferred stock dividend requirement of subsidiary	(4)		(4)		(4)
Preferred stock dividend											(4)		(4)
Ending balance (in shares) at Jun. 30, 2018		517,102,983
Ending balance at Jun. 30, 2018	$ 19,061	$ 12,763	6,059	(13)	18,809	252		258	1,322	8,505	9,127	5	19,217
Beginning balance (in shares) at Dec. 31, 2018	520,338,710	520,338,710					264,374,809
Beginning balance at Dec. 31, 2018	$ 12,903	$ 12,910	(250)	(9)	12,651	252		258	1,322	8,550	2,826	(1)	12,955
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	136		136		136						133		133
Common stock issued, net (in shares)		8,871,568
Common stock issued, net	85	$ 85			85
Stock-based compensation amortization	5	$ 5			5
Ending balance (in shares) at Mar. 31, 2019		529,210,278
Ending balance at Mar. 31, 2019	$ 13,129	$ 13,000	(114)	(9)	12,877	252		258	1,322	8,550	2,959	(1)	13,088
Beginning balance (in shares) at Dec. 31, 2018	520,338,710	520,338,710					264,374,809
Beginning balance at Dec. 31, 2018	$ 12,903	$ 12,910	(250)	(9)	12,651	252		258	1,322	8,550	2,826	(1)	12,955
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	$ (2,413)						$ (2,417)
Ending balance (in shares) at Jun. 30, 2019	529,223,793	529,223,793					264,374,809
Ending balance at Jun. 30, 2019	$ 10,594	$ 13,014	(2,663)	(9)	10,342	252		258	1,322	8,550	409	(1)	10,538
Beginning balance (in shares) at Mar. 31, 2019		529,210,278
Beginning balance at Mar. 31, 2019	13,129	$ 13,000	(114)	(9)	12,877	252		258	1,322	8,550	2,959	(1)	13,088
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	(2,549)		(2,549)		(2,549)		$ (2,550)				(2,550)		(2,550)
Common stock issued, net (in shares)		13,515
Stock-based compensation amortization	$ 14	$ 14			14
Ending balance (in shares) at Jun. 30, 2019	529,223,793	529,223,793					264,374,809
Ending balance at Jun. 30, 2019	$ 10,594	$ 13,014	$ (2,663)	$ (9)	$ 10,342	$ 252		$ 258	$ 1,322	$ 8,550	$ 409	$ (1)	$ 10,538

ORGANIZATION AND BASIS OF PRESE

ORGANIZATION AND BASIS OF PRESENTATION	6 Months Ended
	Jun. 30, 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 as 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 plan 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 was necessary to restore PG&E Corporation’s and the Utility’s financial stability to fund ongoing operations and provide safe service to customers. However, there can be no assurance that such proceedings will restore PG&E Corporation’s and the Utility’s financial stability. On the Petition Date, PG&E Corporation and the Utility filed voluntary petitions for relief under Chapter 11 in the Bankruptcy Court. The Condensed Consolidated Financial Statements do not include any adjustments that might be necessary should PG&E Corporation and the Utility be unable to continue as going concerns. 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 authorized 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	6 Months Ended
	Jun. 30, 2019
Reorganizations [Abstract]
BANKRUPTCY FILING	BANKRUPTCY FILING Chapter 11 Proceedings On January 29, 2019, PG&E Corporation and the Utility 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) as of the Petition Date, are subject to an automatic stay. Absent an order of the Bankruptcy Court providing otherwise, substantially all pre-petition liabilities will be 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. On May 23, 2019, the Bankruptcy Court entered an order (the “Exclusivity Order”) pursuant to section 1121(d) of the Bankruptcy Code, extending PG&E Corporation’s and the Utility’s exclusive periods in which to file a Chapter 11 plan of reorganization (the “Exclusive Filing Period”) and solicit acceptances thereof (the “Exclusive Solicitation Period”). Pursuant to the Exclusivity Order, PG&E Corporation’s and the Utility’s Exclusive Filing Period is extended to, and including, September 26, 2019, and PG&E Corporation’s and the Utility’s Exclusive Solicitation Period is extended to, and including, November 26, 2019. On June 25, 2019, the Ad Hoc Committee of Senior Unsecured Noteholders of the Utility (the “Ad Hoc Noteholder Committee”) submitted a motion, pursuant to section 1121(d)(1) of the Bankruptcy Code, for the entry of an order terminating the Exclusive Filing Period and the Exclusive Solicitation Period. The Ad Hoc Noteholder Committee annexed to its motion a “Term Sheet for Plan of Reorganization.” On July 17, 2019, the Ad Hoc Noteholder Committee filed with the Bankruptcy Court an amended version of the term sheet, along with a commitment letter with respect to certain financings described therein. Certain third parties have filed joinders and statements in support with the Bankruptcy Court with respect to the Ad Hoc Noteholder Committee’s motion, but such parties have not taken any position on the plan construct described by the term sheet. These third parties include TURN, two collective bargaining units representing the Utility’s employees, and the UCC. On July 18, 2019, PG&E Corporation and the Utility filed an objection to the Ad Hoc Noteholder Committee’s motion with the Bankruptcy Court, requesting that the motion be denied. Also on July 18, 2019, the Ad Hoc Group of Subrogation Claim Holders (the “Ad Hoc Subrogation Group”), the TCC, and certain owners of common stock of PG&E Corporation (the “Shareholder Group”) filed objections to the Ad Hoc Noteholder Committee’s motion with the Bankruptcy Court. At a hearing on July 24, 2019, the Bankruptcy Court granted an oral motion of the CPUC and the Governor’s office to adjourn the hearing on the Ad Hoc Noteholder Committee’s motion from July 24, 2019 to August 13, 2019, to allow PG&E Corporation and the Utility, the CPUC, the Governor’s office, and other parties in interest time to engage in discussions regarding the formulation of a potential protocol for the efficient submission and consideration of Chapter 11 plan proposals. The parties are due to provide a status update on these discussions to the Bankruptcy Court on August 9, 2019. On August 7, 2019, the Ad Hoc Noteholder Committee submitted a statement with the Bankruptcy Court, criticizing the protocol proposed by the CPUC and including as an exhibit its own proposed “Alternative Protocol” to govern a competitive plan process. In addition, the Ad Hoc Noteholder Committee annexed to its statement a second amended version of the term sheet and a revised version of the commitment letter. On July 23, 2019, the Ad Hoc Subrogation Group submitted its own motion, pursuant to section 1121(d)(1) of the Bankruptcy Code, to terminate the Exclusive Filing Period and the Exclusive Solicitation Period, which included as an exhibit a “Restructuring Term Sheet.” The hearing before the Bankruptcy Court on the Ad Hoc Subrogation Group’s motion is scheduled for August 13, 2019. On August 6, 2019, PG&E Corporation and the Utility filed an objection to the Ad Hoc Subrogation Group’s motion with the Bankruptcy Court, requesting that the motion be denied. Also on August 6, 2019, the UCC filed a statement in opposition with respect to the Ad Hoc Subrogation Group’s motion, and the Shareholder Group filed an objection to the Ad Hoc Subrogation Group’s motion, both requesting that the motion be denied. On July 1, 2019, the Bankruptcy Court entered an order approving a deadline of October 21, 2019, at 5:00 p.m. (Pacific Time) (the “Bar Date”) for filing claims against PG&E Corporation and the Utility relating to the period prior to the Petition Date. The Bar Date is subject to certain exceptions, including for claims arising under section 503(b)(9) of the Bankruptcy Code, the bar date for which occurred on April 22, 2019. The Bankruptcy Court also approved PG&E Corporation’s and the Utility’s plan to provide notice of the Bar Date to parties-in-interest, including potential wildfire-related claimants and other potential creditors. 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. These accounting standards require the financial statements for periods subsequent to the Petition Date to distinguish transactions and events that are directly associated with the reorganization from the ongoing operations of the business. Expenses, realized gains and losses, and provisions for losses that 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, actions to enforce or otherwise effect the payment of certain claims against PG&E Corporation and the Utility in existence before the Petition Date are 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 June 30, 2019 . Additional claims (which could be LSTC) may arise after the Petition Date resulting from the rejection of executory contracts, including leases, and from the determination by the Bankruptcy Court (or agreement by parties-in-interest) of allowed claims for contingencies and other disputed amounts. PG&E Corporation’s Condensed Consolidated Financial Statements are presented on a consolidated basis and include the accounts of PG&E Corporation and the Utility and other subsidiaries of PG&E Corporation and the Utility that individually and in aggregate are immaterial. Such other subsidiaries did not file for bankruptcy. The Utility’s Condensed Consolidated Financial Statements are presented on a consolidated basis and include the accounts of the Utility and other subsidiaries of the Utility that individually and in aggregate are immaterial. Such other subsidiaries did not file for bankruptcy. Liabilities Subject to Compromise As a result of the commencement of the Chapter 11 Cases, the payment of pre-petition liabilities is subject to compromise or other treatment 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. As described above, 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. 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 June 30, 2019 : (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Financing debt (2) $ 21,811 $ 650 $ 22,461 Wildfire-related claims (3) 18,012 — 18,012 Trade creditors 1,325 4 1,329 Non-qualified benefit plan 18 125 143 2001 bankruptcy disputed claims 221 — 221 Customer deposits & advances 278 — 278 Other 164 2 166 Total Liabilities Subject to Compromise $ 41,829 $ 781 $ 42,610 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) At June 30, 2019 , PG&E Corporation and the Utility had $650 million and $21,526 million in aggregate principal amount of pre-petition indebtedness, respectively. Utility pre-petition 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 information regarding pre-petition wildfire-related claims reported as LSTC. As described in Note 10 under the heading “Plan Support Agr ee ments with Public Entities,” on June 18, 2019, PG&E Corporation and the Utility entered into agreements with certain local public entities to potentially resolve their wildfire-related claims through the Chapter 11 process. Potential Claims PG&E Corporation and the Utility have filed with the Bankruptcy Court schedules and statements of financial affairs setting forth, among other things, the assets and liabilities of PG&E Corporation and the Utility, subject to the assumptions filed in connection therewith. On July 1, 2019, the Bankruptcy Court entered an order approving the Bar Date of October 21, 2019, at 5:00 p.m. (Pacific Time) for filing claims against PG&E Corporation and the Utility relating to the period prior to the Petition Date. The Bar Date is subject to certain exceptions, including for claims arising under section 503(b)(9) of the Bankruptcy Code, the bar date for which occurred on April 22, 2019. Numerous claims have been filed with the Bankruptcy Court against PG&E Corporation and the Utility relating to the period prior to the Petition Date and it is expected that new and amended claims will continue to be filed until the Bar Date, including claims amended to assign value to claims originally filed with no designated value. Through the claims resolution process, differences in amounts scheduled by PG&E Corporation and the Utility and claims filed by creditors will be investigated and resolved, including through the filing of objections with the Bankruptcy Court where appropriate. In light of the substantial number and amount of claims filed, the claims resolution process may take considerable time to complete and will likely continue after PG&E Corporation and the Utility emerge from bankruptcy. The ultimate number and amount of allowed claims is not determinable at this time. 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 approved by the Bankruptcy Court. Cash paid for reorganization items, net was $15 million and $78 million for PG&E Corporation and the Utility, respectively, during the six months ended June 30, 2019 . Reorganization items, net for the three months ended June 30, 2019 and from the Petition Date through June 30, 2019 include the following: Three Months Ended June 30, 2019 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ — $ — $ — Legal and other 75 1 76 Interest income (18 ) (3 ) (21 ) Adjustments to LSTC — — — Trustee fees (2) — 1 1 Total reorganization items, net $ 57 $ (1 ) $ 56 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) PG&E Corporation and the Utility incurred $416,667 and $250,000 , respectively, in fees to the U.S. Trustee in the three months ended June 30, 2019. Petition Date Through June 30, 2019 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 97 $ 17 $ 114 Legal and other 98 2 100 Interest income (27 ) (5 ) (32 ) Adjustments to LSTC — — — Trustee fees (2) — 1 1 Total reorganization items, net $ 168 $ 15 $ 183 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) PG&E Corporation and the Utility incurred $416,667 and $250,000 , respectively, in fees to the U.S. Trustee through June 30, 2019. 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 June 30, 2019 , contractual interest expense of $405 million related to LSTC has not been recorded in the financial statements. The portion of authorized revenues from the Petition Date through June 30, 2019 related to interest expense on pre-petition debt has been deferred as a non-current regulatory liability. The Bankruptcy Court’s Decision on its Authority over PG&E Corporation’s and the Utility’s Rejection of Power Purchase Agreements On June 7, 2019, the Bankruptcy Court granted PG&E Corporation’s and the Utility’s motion for declaratory judgment in an adversary proceeding entitled Pacific Gas & Electric Company v. FERC. In its amended declaratory judgment, the Bankruptcy Court found that FERC had no “concurrent jurisdiction, or any jurisdiction, over the determination of whether any rejections of power purchase contracts by either Debtor should be authorized” pursuant to section 365 of the Bankruptcy Code. The Bankruptcy Court also found that the “Debtors do not need approval from the Federal Energy Regulatory Commission to reject any of their power purchase contracts” and that “[a]ny determinations of the Federal Energy Regulatory Commission” that were contrary to these findings “are void, of no force and effect and not binding on this court or either Debtor.” The Bankruptcy Court further stated that such determinations include, but are not limited to, those previously made in certain FERC proceedings initiated before the Chapter 11 Cases were filed in connection with power purchase contracts with the Utility. On June 12, 2019, the Bankruptcy Court certified its amended declaratory judgment for direct appeal to the United States Court of Appeals for the Ninth Circuit. On July 15, 2019, FERC and certain counterparties to the Utility’s power purchase agreements filed requests for the Ninth Circuit to permit such direct appeal. In addition, on June 26, 2019, the Utility filed a petition for review of those earlier FERC orders also in the Ninth Circuit. 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	6 Months Ended
	Jun. 30, 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 for bankruptcy-related policies 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 June 30, 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 June 30, 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 and six months ended June 30, 2019 and 2018 were as follows: Pension Benefits Other Benefits Three Months Ended June 30, (in millions) 2019 2018 2019 2018 Service cost for benefits earned (1) $ 111 $ 129 $ 14 $ 17 Interest cost 190 172 19 18 Expected return on plan assets (226 ) (256 ) (30 ) (32 ) Amortization of prior service cost (2 ) (2 ) 3 3 Amortization of net actuarial loss — 2 (1 ) (2 ) Net periodic benefit cost 73 45 5 4 Regulatory account transfer (2) 10 39 — — Total $ 83 $ 84 $ 5 $ 4 (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. Pension Benefits Other Benefits Six Months Ended June 30, (in millions) 2019 2018 2019 2018 Service cost for benefits earned (1) $ 222 $ 257 $ 28 $ 33 Interest cost 379 344 38 35 Expected return on plan assets (453 ) (511 ) (61 ) (65 ) Amortization of prior service cost (3 ) (3 ) 7 7 Amortization of net actuarial loss 1 3 (2 ) (3 ) Net periodic benefit cost 146 90 10 7 Regulatory account transfer (2) 21 77 — — Total $ 167 $ 167 $ 10 $ 7 (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, other than the non-qualified pension plan, during the pendency of the Chapter 11 Cases. Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (Loss) The changes, net of income tax, in PG&E Corporation’s accumulated other comprehensive income (loss) are summarized below: Pension Other Total (in millions, net of income tax) Three Months Ended June 30, 2019 Beginning balance $ (21 ) $ 17 $ (4 ) Amounts reclassified from other comprehensive income: Amortization of prior service cost (net of taxes of $1 and $1, respectively) (1) (1 ) 2 1 Amortization of net actuarial loss (net of taxes of $0 and $1, respectively) (1) — — — Regulatory account transfer (net of taxes of $1 and $0, respectively) (1) 1 (2 ) (1 ) Net current period other comprehensive gain (loss) — — — Ending balance $ (21 ) $ 17 $ (4 ) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.) Pension Benefits Other Total (in millions, net of income tax) Three Months Ended June 30, 2018 Beginning balance $ (30 ) $ 17 $ (13 ) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1 and $1, respectively) (1 ) 2 1 Amortization of net actuarial loss (net of taxes of $1 and $1, respectively) 1 (1 ) — Regulatory account transfer (net of taxes of $0 and $0, respectively) — (1 ) (1 ) Net current period other comprehensive gain (loss) — — — 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.) Pension Other Total (in millions, net of income tax) Six Months Ended June 30, 2019 Beginning balance $ (21 ) $ 17 $ (4 ) Amounts reclassified from other comprehensive income: Amortization of prior service cost (net of taxes of $1 and $2, respectively) (1) (2 ) 5 3 Amortization of net actuarial loss (net of taxes of $0 and $1, respectively) (1) 1 (1 ) — Regulatory account transfer (net of taxes of $1 and $1, respectively) (1) 1 (4 ) (3 ) Net current period other comprehensive gain (loss) — — — Ending balance $ (21 ) $ 17 $ (4 ) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.) Pension Other Total (in millions, net of income tax) Six Months Ended June 30, 2018 Beginning balance $ (25 ) $ 17 $ (8 ) Amounts reclassified from other comprehensive income: Amortization of prior service cost (net of taxes of $1 and $2, respectively) (1) (2 ) 5 3 Amortization of net actuarial loss (net of taxes of $1 and $1, respectively) (1) 2 (2 ) — Regulatory account transfer (net of taxes of $0 and $1, respectively) (1) — (3 ) (3 ) Reclassification of stranded income tax to retained earnings (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 case, which generally occur every three or four years . The Utility’s ability to recover revenue requirements authorized by the CPUC in these rate cases is independent, or “decoupled,” from the volume of the Utility’s sales of electricity and natural gas services. The Utility recognizes revenues that have been authorized for rate recovery, are objectively determinable and probable of recovery, and are expected to be collected within 24 months . Generally, electric and natural gas operating revenue is recognized ratably over the year. The Utility records a balancing account asset or liability for differences between customer billings and authorized revenue requirements that are probable of recovery or refund. The CPUC also has authorized the Utility to collect additional revenue requirements to recover costs that the Utility has been authorized to pass on to customers, including costs to purchase electricity and natural gas, and to fund public purpose, demand response, and customer energy efficiency programs. In general, the revenue recognition criteria for pass-through costs billed to customers are met at the time the costs are incurred. The Utility records a regulatory balancing account asset or liability for differences between incurred costs and customer billings or authorized revenue meant to recover those costs, to the extent that these differences are probable of recovery or refund. As a result, these differences have no impact on net income. The following table presents the Utility’s revenues disaggregated by type of customer: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2019 2018 2019 2018 Electric Revenue from contracts with customers Residential $ 994 $ 1,039 $ 2,282 $ 2,375 Commercial 1,135 1,234 2,088 2,307 Industrial 326 354 619 678 Agricultural 261 318 347 443 Public street and highway lighting 16 18 33 38 Other (1) — 84 (309 ) (118 ) Total revenue from contracts with customers - electric 2,732 3,047 5,060 5,723 Regulatory balancing accounts (2) 214 265 678 540 Total electric operating revenue $ 2,946 $ 3,312 $ 5,738 $ 6,263 Natural gas Revenue from contracts with customers Residential $ 343 $ 452 $ 1,515 $ 1,410 Commercial 129 119 369 315 Transportation service only 304 264 686 560 Other (1) (129 ) (128 ) (205 ) (179 ) Total revenue from contracts with customers - gas 647 707 2,365 2,106 Regulatory balancing accounts (2) 350 215 (149 ) (79 ) Total natural gas operating revenue 997 922 2,216 2,027 Total operating revenues $ 3,943 $ 4,234 $ 7,954 $ 8,290 (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. 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 six months ended June 30, 2019 . Cash payments arising from operating leases were $848 million for the six months ended June 30, 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 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 six months ended, June 30, 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 June 30, 2019 , the Utility’s operating leases had a weighted average remaining lease term of 6.1 years and a weighted average discount rate of 6.1% . 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 June 30, 2019 Six Months Ended June 30, 2019 Operating lease fixed cost $ 114 $ 236 Operating lease variable cost 490 799 Total operating lease costs $ 604 $ 1,035 The following table shows the Utility’s future expected operating lease payments: (in millions) June 30, 2019 2019 (1) $ 450 2020 679 2021 623 2022 548 2023 255 Thereafter 692 Total lease payments 3,247 Less imputed interest (594 ) Total $ 2,653 (1) Represents the remaining expected operating lease payments from July 1, 2019 through December 31, 2019. 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 of the guidance on their Condensed Consolidated Financial Statements and related disclosures. Financial Instruments—Credit Losses In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments-Credit Losses (Topic 326), which provides a model, known as the current expected credit loss model, to estimate the expected lifetime credit loss on financial assets, including trade and other receivables, rather than incurred losses over the remaining life of most financial assets measured at amortized cost. The guidance also requires use of an allowance to record estimated credit losses on available-for-sale debt securities. This ASU will be effective for PG&E Corporation and the Utility on January 1, 2020. PG&E Corporation and the Utility are currently evaluating the impact of the guidance on their Condensed Consolidated Financial Statements and related disclosures.

REGULATORY ASSETS, LIABILITIES,

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS	6 Months Ended
	Jun. 30, 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) June 30, 2019 December 31, 2018 Pension benefits (1) $ 1,928 $ 1,947 Environmental compliance costs 997 1,013 Utility retained generation (2) 251 274 Price risk management 67 90 Unamortized loss, net of gain, on reacquired debt (3) 230 76 Catastrophic event memorandum account (4) 918 790 Wildfire expense memorandum account (5) 127 94 Fire hazard prevention memorandum account (6) 291 263 Fire risk mitigation memorandum account (7) 154 — Other 386 417 Total long-term regulatory assets $ 5,349 $ 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. (7) Includes costs associated with the 2019 Wildfire Safety Plan. 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) June 30, 2019 December 31, 2018 Cost of removal obligations (1) $ 6,233 $ 5,981 Deferred income taxes (2) 4 283 Recoveries in excess of AROs (3) 472 356 Public purpose programs (4) 785 674 Employee benefit plans (5) 423 421 Other 1,121 824 Total long-term regulatory liabilities $ 9,038 $ 8,539 (1) Represents the cumulative differences between the recorded costs to remove assets and amounts collected in rates for expected costs to remove assets. (2) Represents the 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) June 30, 2019 December 31, 2018 Electric distribution $ 465 $ 160 Electric transmission 91 128 Utility generation 92 79 Gas distribution and transmission 173 462 Energy procurement 654 168 Public purpose programs 97 111 Other 312 327 Total regulatory balancing accounts receivable $ 1,884 $ 1,435 Payable Balance at (in millions) June 30, 2019 December 31, 2018 Electric transmission 135 134 Gas distribution and transmission 6 9 Energy procurement 308 59 Public purpose programs 610 587 Other 311 287 Total regulatory balancing accounts payable $ 1,370 $ 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	6 Months Ended
	Jun. 30, 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. The DIP Credit Agreement also provides for up to $4.0 billion of incremental facilities in the form of (i) one or more additional tranches of term loans or (ii) one or more increases in the aggregate amount of revolving commitments under the DIP Revolving Facility (together, the “Incremental Facilities”), subject to the terms and conditions set forth therein. The Incremental Facilities are uncommitted and would require approval from the Bankruptcy Court. On the Petition Date, PG&E Corporation and the Utility filed a motion seeking, among other things, interim and final approval of the DIP Facilities, which motion was granted on an interim basis by the Bankruptcy Court following a hearing on January 31, 2019. As a result of the Bankruptcy Court’s interim approval of the DIP Facilities and the satisfaction of the other conditions thereof, the DIP Credit Agreement became effective on February 1, 2019 and a portion of the DIP Revolving Facility in the amount of $ 1.5 billion (including $ 750 million of the letter of credit subfacility) was made available to the Utility. On March 27, 2019, the Bankruptcy Court approved the DIP Facilities on a final basis, authorizing the Utility to borrow up to the remainder of the DIP Revolving Facility (including the remainder of the $ 1.5 billion letter of credit subfacility), the DIP Initial Term Loan Facility and the DIP Delayed Draw Term Loan Facility, in each case subject to the terms and conditions of the DIP Credit Agreement. Borrowings under the DIP Facilities are senior secured obligations of the Utility, secured by substantially all of the Utility’s assets and entitled to superpriority administrative expense claim status in the Utility’s Chapter 11 Case. The Utility’s obligations under the DIP Facilities are guaranteed by PG&E Corporation, and such guarantee is a senior secured obligation of PG&E Corporation, secured by substantially all of PG&E Corporation’s assets and entitled to superpriority administrative expense claim status in PG&E Corporation’s Chapter 11 Case. On 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 June 30, 2019 : (in millions) Termination Date Aggregate Limit Term Loan Borrowings Revolver Borrowings Letters of Credit Outstanding Aggregate Availability DIP Facilities December 2020 (1) $ 5,500 $ 1,500 $ — $ 521 $ 3,479 (1) May be extended to December 2021, subject to satisfaction of certain terms and conditions, including payment of a 25 basis point extension fee. As of June 30, 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 June 30, 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 2047 2.95% to 6.35% 14,600 14,600 Unamortized discount, net of 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) Debt subject to compromise must be reported at the amounts expected to be allowed by the Bankruptcy Court and the carrying values will be adjusted as claims are approved. Total Utility Debt Subject to Compromise does not include $285 million of accrued contractual interest to the Petition Date. At 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 Balance Sheets. See Notes 2 and 4 for further details. (2) At June 30, 2019 , the contractual LIBOR-based interest rate on loans was 3.87% . (3) At June 30, 2019 , the contractual LIBOR-based interest rate on the term loan was 3.60% . (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 matured on June 5, 2019. In December 2015, the maturity dates of the letter of credit facilities supporting the Series 1996 C, E, F, 1997 B bonds were extended to December 1, 2020. Although the stated maturity date of these bonds is 2026, each series will remain outstanding only if the Utility extends or replaces the letter of credit related to the series or otherwise obtains consent from the issuer to the continuation of the series without a credit facility. (6) At June 30, 2019 , the contractual interest rate on the letter of credit facility supporting these bonds was 7.70% . (7) At June 30, 2019 , the contractual interest rate on the letter of credit facility supporting these bonds ranged from 7.70% to 7.83% . (8) Also includes $79 million in letters of credit. (9) At June 30, 2019 , the contractual LIBOR-based interest rate on the loans was 3.67% . (10) At June 30, 2019 , the contractual LIBOR-based interest rate on the term loan was 3.00% .

EQUITY

EQUITY	6 Months Ended
	Jun. 30, 2019
Stockholders' Equity Note [Abstract]
EQUITY	EQUITY There were no issuances under the PG&E Corporation February 2017 equity distribution agreement for the six months ended June 30, 2019 . PG&E Corporation issued common stock under the PG&E Corporation 401(k) plan and share-based compensation plans. During the six months ended June 30, 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	6 Months Ended
	Jun. 30, 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 June 30, Six Months Ended June 30, (in millions, except per share amounts) 2019 2018 2019 2018 Loss attributable to common shareholders $ (2,553 ) $ (984 ) $ (2,420 ) $ (542 ) Weighted average common shares outstanding, basic 529 516 528 516 Add incremental shares from assumed conversions: Employee share-based compensation — — — 1 Weighted average common shares outstanding, diluted 529 516 528 517 Total loss per common share, diluted $ (4.83 ) $ (1.91 ) $ (4.58 ) $ (1.05 ) For each of the periods presented above, the calculation of outstanding common shares on a diluted basis excluded an insignificant amount of options and securities that were antidilutive.

DERIVATIVES

DERIVATIVES	6 Months Ended
	Jun. 30, 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. By order dated April 8, 2019, the Bankruptcy Court authorized the Utility to continue these programs in the ordinary course of business in a manner consistent with its pre-petition practices. Derivatives are presented in the Utility’s Condensed Consolidated Balance Sheets recorded at fair value and on a net basis in accordance with master netting arrangements for each counter-party. The fair value of derivative instruments is further offset by cash collateral paid or received where the right of offset and the intention to offset exist. Price risk management activities that meet the definition of derivatives are recorded at fair value on the Condensed Consolidated Balance Sheets. These instruments are not held for speculative purposes and are subject to certain regulatory requirements. The Utility expects to fully recover in rates all costs related to derivatives under the applicable ratemaking mechanism in place as long as the Utility’s price risk management activities are carried out in accordance with CPUC directives. Therefore, all unrealized gains and losses associated with the change in fair value of these derivatives are deferred and recorded within the Utility’s regulatory assets and liabilities on the Condensed Consolidated Balance Sheets. Net realized gains or losses on commodity derivatives are recorded in the cost of electricity or the cost of natural gas with corresponding increases or decreases to regulatory balancing accounts for recovery from or refund to customers. The Utility elects the normal purchase and sale exception for eligible derivatives. Eligible derivatives are those that require physical delivery in quantities that are expected to be used by the Utility over a reasonable period in the normal course of business, and do not contain pricing provisions unrelated to the commodity delivered. These items are not reflected in the Condensed Consolidated Balance Sheets. Volume of Derivative Activity The volumes of the Utility’s outstanding derivatives were as follows: Contract Volume at Underlying Product Instruments June 30, December 31, Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 174,575,917 177,750,349 Options 16,455,000 13,735,405 Electricity (Megawatt-hours) Forwards, Futures and Swaps 2,999,616 3,833,490 Options 912,033 — Congestion Revenue Rights (3) 329,571,344 340,783,089 (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 June 30, 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 $ 47 $ (4 ) $ 48 $ 91 Other noncurrent assets – other 161 — — 161 Current liabilities – other (25 ) 4 3 (18 ) Noncurrent liabilities – other (67 ) — — (67 ) Total commodity risk $ 116 $ — $ 51 $ 167 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. The majority of the Utility’s derivatives instruments, including power purchase agreements, contain collateral posting provisions tied to the Utility’s credit rating from each of the major credit rating agencies, also known as a credit-risk-related contingent feature. During the first quarter of 2019, multiple credit rating agencies downgraded the Utility’s credit ratings below investment grade, which resulted in the Utility posting additional collateral. As of June 30, 2019

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	6 Months Ended
	Jun. 30, 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 June 30, 2019 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 3,402 $ — $ — $ — $ 3,402 Nuclear decommissioning trusts Short-term investments 16 — — — 16 Global equity securities 1,959 — — — 1,959 Fixed-income securities 815 698 — — 1,513 Assets measured at NAV — — — — 19 Total nuclear decommissioning trusts (2) 2,790 698 — — 3,507 Price risk management instruments (Note 8) Electricity — 13 192 20 225 Gas — 3 — 24 27 Total price risk management instruments — 16 192 44 252 Rabbi trusts Fixed-income securities — 98 — — 98 Life insurance contracts — 71 — — 71 Total rabbi trusts — 169 — — 169 Long-term disability trust Short-term investments 5 — — — 5 Assets measured at NAV — — — — 142 Total long-term disability trust 5 — — — 147 TOTAL ASSETS $ 6,197 $ 883 $ 192 $ 44 $ 7,477 Liabilities: Price risk management instruments (Note 8) Electricity $ — $ 4 $ 83 $ (4 ) $ 83 Gas 2 3 — (3 ) 2 TOTAL LIABILITIES $ 2 $ 7 $ 83 $ (7 ) $ 85 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $491 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 and six months ended June 30, 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) June 30, 2019 Fair Value Measurement Assets Liabilities Valuation Unobservable Range (1) Congestion revenue rights $ 191 $ 64 Market approach CRR auction prices $(13.11) - 22.76 Power purchase agreements $ 1 $ 19 Discounted cash flow Forward prices $ 19.68 - 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 and six months ended June 30, 2019 and 2018 : Price Risk Management Instruments (in millions) 2019 2018 Asset (liability) balance as of April 1 $ 129 $ 40 Net realized and unrealized gains: Included in regulatory assets and liabilities or balancing accounts (1) (20 ) (6 ) Asset (liability) balance as of June 30 $ 109 $ 34 (1) The costs related to price risk management activities are fully passed through to customers in rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted. Price Risk Management Instruments (in millions) 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) 14 (8 ) Asset (liability) balance as of June 30 $ 109 $ 34 (1) The costs related to price risk management activities are fully passed through to customers in rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted. Financial Instruments PG&E Corporation and the Utility use the following methods and assumptions in estimating fair value for financial instruments: the fair values of cash, net accounts receivable; short-term borrowings; accounts payable; and customer deposits to approximate their carrying values at June 30, 2019 and December 31, 2018 , as they are short-term in nature. 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 June 30, 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) 1,500 1,500 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 June 30, 2019 Amortized Total Unrealized Gains Total Unrealized Losses Total Fair Nuclear decommissioning trusts Short-term investments $ 16 $ — $ — $ 16 Global equity securities 496 1,486 (4 ) 1,978 Fixed-income securities 1,431 84 (2 ) 1,513 Total (1) $ 1,943 $ 1,570 $ (6 ) $ 3,507 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 $491 million and $408 million for the periods ended June 30, 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) June 30, 2019 Less than 1 year $ 26 1–5 years 541 5–10 years 340 More than 10 years 606 Total maturities of fixed-income securities $ 1,513 The following table provides a summary of activity for fixed income and equity securities: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2019 2018 2019 2018 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 171 $ 308 $ 517 $ 802 Gross realized gains on securities 56 11 22 48 Gross realized losses on securities (26 ) (5 ) (7 ) (9 )

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES	6 Months Ended
	Jun. 30, 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. At June 30, 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) June 30, 2019 December 31, 2018 2015 Butte fire $ 212 $ 226 2017 Northern California wildfires 5,500 3,500 2018 Camp fire 12,400 10,500 Total wildfire-related claims (1) $ 18,112 $ 14,226 (1) On the Petition Date, all wildfire-related claims were classified as LSTC and all pending litigation was stayed. As of June 30, 2019, $ 100 million was reclassified from LSTC to current liabilities - wildfire-related claims to reflect Bankruptcy Court approval of contributions to the Wildfire Assistance Fund. In addition, during the three and six months ended June 30, 2019 , the Utility incurred legal and other costs of $19 million and $32 million , respectively, related to the 2018 Camp fire, with no corresponding costs in the same periods in 2018. During the three and six months ended June 30, 2019 , the Utility incurred legal and other costs of $7 million and $41 million , respectively, related to the 2017 Northern California wildfires, as compared to $46 million and $68 million , respectively, in the same periods in 2018. 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 July 9, 2019 (the “Cal Fire website”) indicated that the 2018 Camp fire consumed 153,336 acres. On the Cal Fire website, Cal Fire reported 85 fatalities and the destruction of 13,972 residences, 528 commercial structures and 4,293 other buildings resulting from the 2018 Camp fire. There have been no subsequent updates of this information on the Cal Fire website. On May 15, 2019, Cal Fire issued a news release announcing the results of its investigation into the cause of the 2018 Camp fire. According to the news release: • Cal Fire determined that the 2018 Camp fire was caused by electrical transmission lines owned and operated by the Utility near Pulga, California. • Cal Fire identified a second ignition site and stated that the second fire was consumed by the original fire which started earlier near Pulga, California. Cal Fire stated that the cause of the second fire was determined to be “vegetation into electrical distribution lines owned and operated by” the Utility. Cal Fire indicated in its news release that its investigation report for the 2018 Camp fire has been forwarded to the Butte County District Attorney. (See “District Attorneys’ Offices’ Investigations” below for further information regarding the investigations of the 2018 Camp fire.) As of the date of this filing, this investigation report has not been released publicly. PG&E Corporation and the Utility accept Cal Fire’s determination that the 2018 Camp fire ignited at the first ignition site. PG&E Corporation and the Utility have not been able to form a conclusion as to whether a second fire ignited as a result of vegetation contact with the Utility’s facilities. PG&E Corporation and the Utility are continuing to review the evidence concerning the 2018 Camp fire. PG&E Corporation and the Utility have not yet had access to all of the evidence collected by Cal Fire as part of its investigation or to the investigation report prepared by Cal Fire. Further, the CPUC’s SED is conducting investigations to assess the compliance of electric and communication companies’ facilities with applicable rules and regulations in areas impacted by the 2018 Camp fire. 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 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 19 investigation reports and two supplementary investigation reports that include its determination of the causes of 21 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. 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 stated in its news releases that the McCourtney, Lobo, Sulphur, Blue, Norrbom, Adobe, Partrick, Pythian, Pocket and Atlas fire 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. During the second quarter of 2019, Cal Fire released its investigation reports related to the Sulphur, Blue, Norrbom, Adobe, Partrick, Pythian, Pocket and Atlas fires. The Cal Fire investigation report for the Adobe fire included as Attachment 42.1 a “Supplementary Investigation Report” concerning the Pressley fire. The Cal Fire investigator concludes in the Supplementary Investigation Report that the Pressley fire was started by an ember cast from the Adobe fire. On July 24, 2019, the CPUC released copies of Cal Fire’s investigation report related to the Point fire and supplementary investigation reports related to the Youngs fire, which Cal Fire had not previously released publicly, as attachments to the SED’s own investigative reports for those fires. (The Youngs fire is the fire that the Utility has previously referred to as the Maacama fire.) The Cal Fire investigation report for the Point fire alleges that the fire was caused by a tree limb that broke off in high winds and fell into a power line, causing the power line to contact the ground. The Cal Fire investigators in the Youngs supplementary reports conclude that the fire was caused by a tree that fell into a power line, severing the line. Cal Fire has not yet released its investigation reports related to the McCourtney and Lobo fires because Cal Fire referred its investigations into these fires to local law enforcement and the information contained in its investigation reports related to these fires remains confidential. As described in Note 11, on June 27, 2019, the CPUC issued an OII disclosing the findings of a June 13, 2019 report by the SED, which, among other things, alleges that the Utility committed 27 violations in connection with 12 of the 2017 Northern California wildfires (specifically, the Adobe, Atlas, Cascade, Norrbom, Nuns, Oakmont/Pythian, Partrick, Pocket, Point, Potter/Redwood, Sulphur and Youngs fires). As described in the OII, the 27 alleged violations include failure to maintain vegetation clearances, failure to identify and abate hazardous trees, improper record keeping, incomplete patrol prior to re-energizing a circuit, failure to retain evidence, failure to report an incident, and failure to maintain clearances between lines. No violations were identified by the SED in connection with the Cherokee, La Porte and Tubbs fires. The 37 fire was determined by the SED to no t be a reportable incident. The SED report does not address the Lobo and McCourtney fires because Cal Fire referred its investigations into these fires to local law enforcement and the information contained in its investigation reports related to these fires remains confidential. On a status conference call before the assigned ALJ on July 29, 2019, the SED informed the parties that because the Nevada County District Attorney had decided not to pursue criminal charges in connection with the Lobo and McCourtney fires, the SED may add alleged violations related to those fires and the 2018 Camp fire to the OII. As required by the OII, on July 29, 2019, the Utility filed its initial response to the OII. In the initial response, the Utility indicated that it intends to fully cooperate with the CPUC but also stated that it disagreed with certain of the alleged violations set forth in the OII. The Utility also filed a Corrective Actions Report and an Application to Develop a Mobile Application and Supporting Systems, both as required by the OII. Also as required by the OII, on August 5, 2019, the Utility submitted a report to respond to the information requests contained in the OII, relating to matters such as the Utility’s vegetation management procedures and practices, its use of recloser devices in high fire risk areas, its pro-active de-energization of powerlines during times of high fire danger and its recordkeeping and other practices. Further, the SED is conducting investigations into certain of the other 2017 Northern California wildfires, including the McCourtney and Lobo fires. Various other entities 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. 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, before the automatic stay arising as a result of the filing of the Chapter 11 Cases, PG&E Corporation and the Utility were aware of approximately 100 complaints on behalf of at least 4,200 plaintiffs related to the 2018 Camp fire, nine of which sought to be certified as class actions. The pending civil litigation against PG&E Corporation and the Utility related to the 2018 Camp fire, which is currently stayed as a result of the commencement of the Chapter 11 Cases, included claims under multiple theories of liability, including inverse condemnation, trespass, private nuisance, public nuisance, negligence, negligence per se, negligent interference with prospective economic advantage, negligent infliction of emotional distress, premises liability, violations of the Public Utilities Code, violations of the Health & Safety Code, malice and false advertising in violation of the California Business and Professions Code. The plaintiffs principally asserted that PG&E Corporation’s and the Utility’s alleged failure to maintain and repair their distribution and transmission lines and failure to properly maintain the vegetation surrounding such lines were the causes of the 2018 Camp fire. The plaintiffs sought damages and remedies that include wrongful death, personal injury, property damage, evacuation costs, medical expenses, establishment of a class action medical monitoring fund, punitive damages, attorneys’ fees and other damages. 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, before the automatic stay arising as a result of the filing of the Chapter 11 Cases, PG&E Corporation and the Utility were aware of approximately 750 complaints on behalf of at least 3,800 plaintiffs related to the 2017 Northern California wildfires, five of which sought to be certified as class actions. These cases were coordinated in the San Francisco County Superior Court. As of the Petition Date, the coordinated litigation was in the early stages of discovery. A trial with respect to the Atlas fire was scheduled to begin on September 23, 2019. The pending civil litigation against PG&E Corporation and the Utility related to the 2017 Northern California wildfires, included claims under multiple theories of liability, including inverse condemnation, trespass, private nuisance and negligence. This litigation, including the trial date with respect to the Atlas fire, currently is stayed as a result of the commencement of the Chapter 11 Cases. The plaintiffs principally asserted that PG&E Corporation’s and the Utility’s alleged failure to maintain and repair their distribution and transmission lines and failure to properly maintain the vegetation surrounding such lines were the causes of the 2017 Northern California wildfires. The plaintiffs sought damages 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. However, the TCC has submitted a motion to the Bankruptcy Court seeking relief from the automatic stay to enable certain plaintiffs to pursue their claims outside of the Chapter 11 process, as further described under the heading “Motions to Lift the Automatic Stay for Certain Tubbs Fire-Related Claims” below. PG&E Corporation and the Utility have opposed such motions. Insurance carriers who have made payments to their insureds for property damage arising out of the 2017 Northern California wildfires filed 52 subrogation complaints in the San Francisco County Superior Court and the Sonoma County Superior Court as of January 28, 2019. These complaints allege, among other things, negligence, inverse condemnation, trespass and nuisance. The allegations were 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. However, certain holders of subrogation claims have submitted motions to the Bankruptcy Court seeking relief from the automatic stay in order to pursue their claims outside of the Chapter 11 process, as further described under the heading “Motions to Lift the Automatic Stay for Certain Tubbs Fire-Related Claims” below. PG&E Corporation and the Utility have opposed such motions. Various government entities, including Yuba, Nevada, Lake, Mendocino, Napa and Sonoma Counties and the Cities of Santa Rosa and Clearlake, also asserted claims against PG&E Corporation and the Utility based on the damages that these government entities allegedly suffered as a result of the 2017 Northern California wildfires. Such alleged damages included, among other things, loss of natural resources, loss of public parks, property damages and fire suppression costs. The causes of action and allegations were similar to the ones made by individual plaintiffs and the insurance carriers. With respect to the 2018 Camp fire, Butte County has filed similar claims against PG&E Corporation and the Utility. As described below under the heading “Plan Support Agreements with Public Entities,” on June 18, 2019, PG&E Corporation and the Utility entered into agreements with certain government entities to potentially resolve their wildfire-related claims through the Chapter 11 process. As described in Note 2, on July 1, 2019, the Bankruptcy Court entered an order approving the Bar Date of October 21, 2019, at 5:00 p.m. (Pacific Time) for filing claims against PG&E Corporation and the Utility relating to the period prior to the Petition Date, including claims in connection with the 2018 Camp fire and the 2017 Northern California wildfires. The Bar Date is subject to certain exceptions, including for claims arising under section 503(b)(9) of the Bankruptcy Code, the bar date for which occurred on April 22, 2019. It is expected that numerous wildfire-related claims will be filed against PG&E Corporation and the Utility in connection with the 2018 Camp fire and the 2017 Northern California wildfires through the Bar Date. On July 18, 2019, PG&E Corporation and the Utility filed a motion for entry of an order establishing procedures and schedules for the estimation of PG&E Corporation’s and the Utility’s aggregate liability for certain claims arising out of the 2018 Camp fire and the 2017 Northern California wildfires, as further described under the heading “Motion for the Establishment of Wildfire Claims Estimation Procedures” below. 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 the McCourtney and Lobo investigation reports prepared by Cal Fire. PG&E Corporation and the Utility and plaintiffs have reached an agreement to transfer available evidence collected by Cal Fire for the fires for which its investigation reports have been released to a shared storage facility. The transfer of the evidence is not yet complete. (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. As discussed under the heading “Plan Support Agreements with Public Entities,” PG&E Corporation and the Utility have entered into agreements with certain government entity claimholders to potentially resolve their wildfire-related claims. The most recent settlement offers made by PG&E Corporation and the Utility to subrogated insurance claimholders and individual claimholders as of the date of this filing are discussed in further detail below under the heading “2018 Camp Fire and 2017 Northern California Wildfires Accounting Charge.” PG&E Corporation and the Utility cannot predict the outcome or timing of discussions with other claimholders. Even if discussions with claimholders were successful, the consummation of such a global settlement would likely be contingent on numerous uncertain conditions, including Bankruptcy Court approval and governmental action. 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. Motions to Lift the Automatic Stay for Certain Tubbs Fire-Related Claims On July 2, 2019, the TCC submitted a motion, pursuant to section 362(d)(1) of the Bankruptcy Code, for entry of an order terminating the automatic stay to permit certain individual plaintiffs (the “Tubbs Preference Plaintiffs”) to proceed to a jury trial on their claims against PG&E Corporation and the Utility arising from the Tubbs fire, and to request the San Francisco Superior Court in the coordinated litigation for the 2017 Northern California wildfires to order one or more of the cases of the Tubbs Preference Plaintiffs to trial with preference pursuant to California Code of Civil Procedure section 36. On July 9, 2019, the TCC submitted an amended motion to request relief from the stay with respect to additional individual plaintiffs to proceed to a jury trial on their claims against PG&E Corporation and the Utility arising from the Tubbs fire. On July 3, 2019, the Ad Hoc Subrogation Group submitted a motion for relief from the automatic stay to permit certain of the Ad Hoc Subrogation Group’s members to pursue their claims against PG&E Corporation and the Utility regarding the issue of PG&E Corporation’s and the Utility’s liability for the Tubbs fire in the San Francisco Superior Court in the coordinated litigation for the 2017 Northern California wildfires. On July 19, 2019, PG&E Corporation and the Utility filed an objection to the motions of the TCC and the Ad Hoc Subrogation Group, requesting that the motions be denied. Also on July 19, 2019, the UCC and the Shareholder Group filed objections to the motions of the TCC and the Ad Hoc Subrogation Group with the Bankruptcy Court, requesting that the motions be denied. The Shareholder Group also joined in PG&E Corporation’s and the Utility’s objection to the motions of the TCC and the Ad Hoc Subrogation Group. On July 22, 2019, the Bankruptcy Court issued an order continuing the hearings on the TCC’s and the Ad Hoc Subrogation Group’s motions for relief from the automatic stay to August 14, 2019. Motion for the Establishment of Wildfire Claims Estimation Procedures On July 18, 2019, PG&E Corporation and the Utility submitted a motion, pursuant to sections 105(a) and 502(c) of the Bankruptcy Code, for entry of an order establishing procedures and schedules for the estimation of PG&E Corporation’s and the Utility’s aggregate liability for contingent and/or unliquidated claims arising out of the 2015 Butte fire, the 2017 Northern California wildfires and the 2018 Camp fire (which are collectively referred to in this paragraph as “wildfire claims”). In the motion, PG&E Corporation and the Utility proposed, among other things, the following general parameters of the estimation process: • First, the Bankruptcy Court would address the legal issue of whether, pursuant to the state law doctrine of inverse condemnation, PG&E Corporation and the Utility may be held strictly liable for wildfire claims asserting property damages even where PG&E Corporation or the Utility were not negligent. • Second, the Bankruptcy Court would schedule a hearing on the limited issue of causation of the Tubbs fire on October 7, 2019, or as soon as possible thereafter. • Third, following the Bar Date, the Bankruptcy Court would determine the aggregate value of the wildfire claims in a hearing proposed to be scheduled for early December 2019. This phase of the estimation process would involve the resolution of questions around the likelihood of success of the wildfire claims on issues such as negligence, the recoverability of certain categories of damages and the aggregate estimate of overall damages based upon sampling of claims and expert testimony. In the motion, PG&E Corporation and the Utility indicated that they are prepared to agree that, as part of the proposed estimation process, they will not contest causation with respect to any wildfire for which Cal Fire has concluded that PG&E Corporation and the Utility are responsible, including the 2018 Camp fire and the 2017 Northern California wildfires identified above, except the Tubbs fire. The motion is expected to be heard by the Bankruptcy Court on August 14, 2019. On August 7, 2019, certain third parties filed joinders and statements in support with the Bankruptcy Court with respect to PG&E Corporation’s and the Utility’s motion, including the Ad Hoc Noteholder Committee, the UCC and the Shareholder Group. Also on August 7, 2019, certain third parties filed objections to PG&E Corporation’s and the Utility’s motion with the Bankruptcy Court, including the City and County of San Francisco, the Ad Hoc Subrogation Group and the TCC. The objection of the City and County of San Francisco is limited to PG&E Corporation’s and the Utility’s proposal for the Bankruptcy Court to address the legal issue of whether, under the doctrine of inverse condemnation, PG&E Corporation and the Utility may be held strictly liable for wildfire claims asserting property damages even where it was not negligent. Plan Support Agreements with Public Entities On June 18, 2019, PG&E Corporation and the Utility entered into PSAs with certain local public entities providing for an aggregate of $1.0 billion to be paid by PG&E Corporation and the Utility to such public entities pursuant to PG&E Corporation and the Utility’s Chapter 11 plan of reorganization in order to settle such public entities’ claims against PG&E Corporation and the Utility relating to the 2018 Camp fire, 2017 Northern California wildfires and 2015 Butte fire (collectively, “Public Entity Wildfire Claims”). PG&E Corporation and the Utility’s Chapter 11 plan of reorganization currently is under development and has not yet been filed with the Bankruptcy Court. PG&E Corporation and the Utility have entered into a PSA with each of the following public entities or group of public entities, as applicable: • the City of Clearlake, the City of Napa, the City of Santa Rosa, the County of Lake, the Lake County Sanitation District, the County of Mendocino, Napa County, the County of Nevada, the County of Sonoma, the Sonoma County Agricultural Preservation and Open Space District, the Sonoma County Community Development Commission, the Sonoma County Water Agency, the Sonoma Valley County Sanitation District and the County of Yuba (collectively, the “2017 Northern California Wildfire Public Entities”); • the Town of Paradise; • the County of Butte; • the Paradise Recreation & Park District; • the County of Yuba; and • the Calaveras County Water District. For purposes of each PSA, the local public entities that are party to such PSA are referred to herein as “Supporting Public Entities.” Each PSA provides that PG&E Corporation and the Utility’s Chapter 11 plan of reorganization will include, among other things, the following elements: • following the effective date of PG&E Corporation and the Utility’s Chapter 11 plan of reorganization, PG&E Corporation and the Utility will remit a Settlement Amount (as defined below) in the amount set forth below to the applicable Supporting Public Entities in full and final satisfaction and discharge of their Public Entity Wildfire Claims, and • subject to the Supporting Public Entities voting affirmatively to accept PG&E Corporation and the Utility’s Chapter 11 plan of reorganization, following the effective date of PG&E Corporation and the Utility’s Chapter 11 plan of reorganization, PG&E Corporation and the Utility will create and promptly fund $10.0 million to a segregated fund to be used by the Supporting Public Entities collectively in connection with the defense or resolution of claims against the Supporting Public Entities by

OTHER CONTINGENCIES AND COMMITM

OTHER CONTINGENCIES AND COMMITMENTS	6 Months Ended
	Jun. 30, 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. At June 30, 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) June 30, 2019 December 31, 2018 2015 Butte fire $ 212 $ 226 2017 Northern California wildfires 5,500 3,500 2018 Camp fire 12,400 10,500 Total wildfire-related claims (1) $ 18,112 $ 14,226 (1) On the Petition Date, all wildfire-related claims were classified as LSTC and all pending litigation was stayed. As of June 30, 2019, $ 100 million was reclassified from LSTC to current liabilities - wildfire-related claims to reflect Bankruptcy Court approval of contributions to the Wildfire Assistance Fund. In addition, during the three and six months ended June 30, 2019 , the Utility incurred legal and other costs of $19 million and $32 million , respectively, related to the 2018 Camp fire, with no corresponding costs in the same periods in 2018. During the three and six months ended June 30, 2019 , the Utility incurred legal and other costs of $7 million and $41 million , respectively, related to the 2017 Northern California wildfires, as compared to $46 million and $68 million , respectively, in the same periods in 2018. 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 July 9, 2019 (the “Cal Fire website”) indicated that the 2018 Camp fire consumed 153,336 acres. On the Cal Fire website, Cal Fire reported 85 fatalities and the destruction of 13,972 residences, 528 commercial structures and 4,293 other buildings resulting from the 2018 Camp fire. There have been no subsequent updates of this information on the Cal Fire website. On May 15, 2019, Cal Fire issued a news release announcing the results of its investigation into the cause of the 2018 Camp fire. According to the news release: • Cal Fire determined that the 2018 Camp fire was caused by electrical transmission lines owned and operated by the Utility near Pulga, California. • Cal Fire identified a second ignition site and stated that the second fire was consumed by the original fire which started earlier near Pulga, California. Cal Fire stated that the cause of the second fire was determined to be “vegetation into electrical distribution lines owned and operated by” the Utility. Cal Fire indicated in its news release that its investigation report for the 2018 Camp fire has been forwarded to the Butte County District Attorney. (See “District Attorneys’ Offices’ Investigations” below for further information regarding the investigations of the 2018 Camp fire.) As of the date of this filing, this investigation report has not been released publicly. PG&E Corporation and the Utility accept Cal Fire’s determination that the 2018 Camp fire ignited at the first ignition site. PG&E Corporation and the Utility have not been able to form a conclusion as to whether a second fire ignited as a result of vegetation contact with the Utility’s facilities. PG&E Corporation and the Utility are continuing to review the evidence concerning the 2018 Camp fire. PG&E Corporation and the Utility have not yet had access to all of the evidence collected by Cal Fire as part of its investigation or to the investigation report prepared by Cal Fire. Further, the CPUC’s SED is conducting investigations to assess the compliance of electric and communication companies’ facilities with applicable rules and regulations in areas impacted by the 2018 Camp fire. 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 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 19 investigation reports and two supplementary investigation reports that include its determination of the causes of 21 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. 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 stated in its news releases that the McCourtney, Lobo, Sulphur, Blue, Norrbom, Adobe, Partrick, Pythian, Pocket and Atlas fire 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. During the second quarter of 2019, Cal Fire released its investigation reports related to the Sulphur, Blue, Norrbom, Adobe, Partrick, Pythian, Pocket and Atlas fires. The Cal Fire investigation report for the Adobe fire included as Attachment 42.1 a “Supplementary Investigation Report” concerning the Pressley fire. The Cal Fire investigator concludes in the Supplementary Investigation Report that the Pressley fire was started by an ember cast from the Adobe fire. On July 24, 2019, the CPUC released copies of Cal Fire’s investigation report related to the Point fire and supplementary investigation reports related to the Youngs fire, which Cal Fire had not previously released publicly, as attachments to the SED’s own investigative reports for those fires. (The Youngs fire is the fire that the Utility has previously referred to as the Maacama fire.) The Cal Fire investigation report for the Point fire alleges that the fire was caused by a tree limb that broke off in high winds and fell into a power line, causing the power line to contact the ground. The Cal Fire investigators in the Youngs supplementary reports conclude that the fire was caused by a tree that fell into a power line, severing the line. Cal Fire has not yet released its investigation reports related to the McCourtney and Lobo fires because Cal Fire referred its investigations into these fires to local law enforcement and the information contained in its investigation reports related to these fires remains confidential. As described in Note 11, on June 27, 2019, the CPUC issued an OII disclosing the findings of a June 13, 2019 report by the SED, which, among other things, alleges that the Utility committed 27 violations in connection with 12 of the 2017 Northern California wildfires (specifically, the Adobe, Atlas, Cascade, Norrbom, Nuns, Oakmont/Pythian, Partrick, Pocket, Point, Potter/Redwood, Sulphur and Youngs fires). As described in the OII, the 27 alleged violations include failure to maintain vegetation clearances, failure to identify and abate hazardous trees, improper record keeping, incomplete patrol prior to re-energizing a circuit, failure to retain evidence, failure to report an incident, and failure to maintain clearances between lines. No violations were identified by the SED in connection with the Cherokee, La Porte and Tubbs fires. The 37 fire was determined by the SED to no t be a reportable incident. The SED report does not address the Lobo and McCourtney fires because Cal Fire referred its investigations into these fires to local law enforcement and the information contained in its investigation reports related to these fires remains confidential. On a status conference call before the assigned ALJ on July 29, 2019, the SED informed the parties that because the Nevada County District Attorney had decided not to pursue criminal charges in connection with the Lobo and McCourtney fires, the SED may add alleged violations related to those fires and the 2018 Camp fire to the OII. As required by the OII, on July 29, 2019, the Utility filed its initial response to the OII. In the initial response, the Utility indicated that it intends to fully cooperate with the CPUC but also stated that it disagreed with certain of the alleged violations set forth in the OII. The Utility also filed a Corrective Actions Report and an Application to Develop a Mobile Application and Supporting Systems, both as required by the OII. Also as required by the OII, on August 5, 2019, the Utility submitted a report to respond to the information requests contained in the OII, relating to matters such as the Utility’s vegetation management procedures and practices, its use of recloser devices in high fire risk areas, its pro-active de-energization of powerlines during times of high fire danger and its recordkeeping and other practices. Further, the SED is conducting investigations into certain of the other 2017 Northern California wildfires, including the McCourtney and Lobo fires. Various other entities 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. 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, before the automatic stay arising as a result of the filing of the Chapter 11 Cases, PG&E Corporation and the Utility were aware of approximately 100 complaints on behalf of at least 4,200 plaintiffs related to the 2018 Camp fire, nine of which sought to be certified as class actions. The pending civil litigation against PG&E Corporation and the Utility related to the 2018 Camp fire, which is currently stayed as a result of the commencement of the Chapter 11 Cases, included claims under multiple theories of liability, including inverse condemnation, trespass, private nuisance, public nuisance, negligence, negligence per se, negligent interference with prospective economic advantage, negligent infliction of emotional distress, premises liability, violations of the Public Utilities Code, violations of the Health & Safety Code, malice and false advertising in violation of the California Business and Professions Code. The plaintiffs principally asserted that PG&E Corporation’s and the Utility’s alleged failure to maintain and repair their distribution and transmission lines and failure to properly maintain the vegetation surrounding such lines were the causes of the 2018 Camp fire. The plaintiffs sought damages and remedies that include wrongful death, personal injury, property damage, evacuation costs, medical expenses, establishment of a class action medical monitoring fund, punitive damages, attorneys’ fees and other damages. 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, before the automatic stay arising as a result of the filing of the Chapter 11 Cases, PG&E Corporation and the Utility were aware of approximately 750 complaints on behalf of at least 3,800 plaintiffs related to the 2017 Northern California wildfires, five of which sought to be certified as class actions. These cases were coordinated in the San Francisco County Superior Court. As of the Petition Date, the coordinated litigation was in the early stages of discovery. A trial with respect to the Atlas fire was scheduled to begin on September 23, 2019. The pending civil litigation against PG&E Corporation and the Utility related to the 2017 Northern California wildfires, included claims under multiple theories of liability, including inverse condemnation, trespass, private nuisance and negligence. This litigation, including the trial date with respect to the Atlas fire, currently is stayed as a result of the commencement of the Chapter 11 Cases. The plaintiffs principally asserted that PG&E Corporation’s and the Utility’s alleged failure to maintain and repair their distribution and transmission lines and failure to properly maintain the vegetation surrounding such lines were the causes of the 2017 Northern California wildfires. The plaintiffs sought damages 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. However, the TCC has submitted a motion to the Bankruptcy Court seeking relief from the automatic stay to enable certain plaintiffs to pursue their claims outside of the Chapter 11 process, as further described under the heading “Motions to Lift the Automatic Stay for Certain Tubbs Fire-Related Claims” below. PG&E Corporation and the Utility have opposed such motions. Insurance carriers who have made payments to their insureds for property damage arising out of the 2017 Northern California wildfires filed 52 subrogation complaints in the San Francisco County Superior Court and the Sonoma County Superior Court as of January 28, 2019. These complaints allege, among other things, negligence, inverse condemnation, trespass and nuisance. The allegations were 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. However, certain holders of subrogation claims have submitted motions to the Bankruptcy Court seeking relief from the automatic stay in order to pursue their claims outside of the Chapter 11 process, as further described under the heading “Motions to Lift the Automatic Stay for Certain Tubbs Fire-Related Claims” below. PG&E Corporation and the Utility have opposed such motions. Various government entities, including Yuba, Nevada, Lake, Mendocino, Napa and Sonoma Counties and the Cities of Santa Rosa and Clearlake, also asserted claims against PG&E Corporation and the Utility based on the damages that these government entities allegedly suffered as a result of the 2017 Northern California wildfires. Such alleged damages included, among other things, loss of natural resources, loss of public parks, property damages and fire suppression costs. The causes of action and allegations were similar to the ones made by individual plaintiffs and the insurance carriers. With respect to the 2018 Camp fire, Butte County has filed similar claims against PG&E Corporation and the Utility. As described below under the heading “Plan Support Agreements with Public Entities,” on June 18, 2019, PG&E Corporation and the Utility entered into agreements with certain government entities to potentially resolve their wildfire-related claims through the Chapter 11 process. As described in Note 2, on July 1, 2019, the Bankruptcy Court entered an order approving the Bar Date of October 21, 2019, at 5:00 p.m. (Pacific Time) for filing claims against PG&E Corporation and the Utility relating to the period prior to the Petition Date, including claims in connection with the 2018 Camp fire and the 2017 Northern California wildfires. The Bar Date is subject to certain exceptions, including for claims arising under section 503(b)(9) of the Bankruptcy Code, the bar date for which occurred on April 22, 2019. It is expected that numerous wildfire-related claims will be filed against PG&E Corporation and the Utility in connection with the 2018 Camp fire and the 2017 Northern California wildfires through the Bar Date. On July 18, 2019, PG&E Corporation and the Utility filed a motion for entry of an order establishing procedures and schedules for the estimation of PG&E Corporation’s and the Utility’s aggregate liability for certain claims arising out of the 2018 Camp fire and the 2017 Northern California wildfires, as further described under the heading “Motion for the Establishment of Wildfire Claims Estimation Procedures” below. 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 the McCourtney and Lobo investigation reports prepared by Cal Fire. PG&E Corporation and the Utility and plaintiffs have reached an agreement to transfer available evidence collected by Cal Fire for the fires for which its investigation reports have been released to a shared storage facility. The transfer of the evidence is not yet complete. (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. As discussed under the heading “Plan Support Agreements with Public Entities,” PG&E Corporation and the Utility have entered into agreements with certain government entity claimholders to potentially resolve their wildfire-related claims. The most recent settlement offers made by PG&E Corporation and the Utility to subrogated insurance claimholders and individual claimholders as of the date of this filing are discussed in further detail below under the heading “2018 Camp Fire and 2017 Northern California Wildfires Accounting Charge.” PG&E Corporation and the Utility cannot predict the outcome or timing of discussions with other claimholders. Even if discussions with claimholders were successful, the consummation of such a global settlement would likely be contingent on numerous uncertain conditions, including Bankruptcy Court approval and governmental action. 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. Motions to Lift the Automatic Stay for Certain Tubbs Fire-Related Claims On July 2, 2019, the TCC submitted a motion, pursuant to section 362(d)(1) of the Bankruptcy Code, for entry of an order terminating the automatic stay to permit certain individual plaintiffs (the “Tubbs Preference Plaintiffs”) to proceed to a jury trial on their claims against PG&E Corporation and the Utility arising from the Tubbs fire, and to request the San Francisco Superior Court in the coordinated litigation for the 2017 Northern California wildfires to order one or more of the cases of the Tubbs Preference Plaintiffs to trial with preference pursuant to California Code of Civil Procedure section 36. On July 9, 2019, the TCC submitted an amended motion to request relief from the stay with respect to additional individual plaintiffs to proceed to a jury trial on their claims against PG&E Corporation and the Utility arising from the Tubbs fire. On July 3, 2019, the Ad Hoc Subrogation Group submitted a motion for relief from the automatic stay to permit certain of the Ad Hoc Subrogation Group’s members to pursue their claims against PG&E Corporation and the Utility regarding the issue of PG&E Corporation’s and the Utility’s liability for the Tubbs fire in the San Francisco Superior Court in the coordinated litigation for the 2017 Northern California wildfires. On July 19, 2019, PG&E Corporation and the Utility filed an objection to the motions of the TCC and the Ad Hoc Subrogation Group, requesting that the motions be denied. Also on July 19, 2019, the UCC and the Shareholder Group filed objections to the motions of the TCC and the Ad Hoc Subrogation Group with the Bankruptcy Court, requesting that the motions be denied. The Shareholder Group also joined in PG&E Corporation’s and the Utility’s objection to the motions of the TCC and the Ad Hoc Subrogation Group. On July 22, 2019, the Bankruptcy Court issued an order continuing the hearings on the TCC’s and the Ad Hoc Subrogation Group’s motions for relief from the automatic stay to August 14, 2019. Motion for the Establishment of Wildfire Claims Estimation Procedures On July 18, 2019, PG&E Corporation and the Utility submitted a motion, pursuant to sections 105(a) and 502(c) of the Bankruptcy Code, for entry of an order establishing procedures and schedules for the estimation of PG&E Corporation’s and the Utility’s aggregate liability for contingent and/or unliquidated claims arising out of the 2015 Butte fire, the 2017 Northern California wildfires and the 2018 Camp fire (which are collectively referred to in this paragraph as “wildfire claims”). In the motion, PG&E Corporation and the Utility proposed, among other things, the following general parameters of the estimation process: • First, the Bankruptcy Court would address the legal issue of whether, pursuant to the state law doctrine of inverse condemnation, PG&E Corporation and the Utility may be held strictly liable for wildfire claims asserting property damages even where PG&E Corporation or the Utility were not negligent. • Second, the Bankruptcy Court would schedule a hearing on the limited issue of causation of the Tubbs fire on October 7, 2019, or as soon as possible thereafter. • Third, following the Bar Date, the Bankruptcy Court would determine the aggregate value of the wildfire claims in a hearing proposed to be scheduled for early December 2019. This phase of the estimation process would involve the resolution of questions around the likelihood of success of the wildfire claims on issues such as negligence, the recoverability of certain categories of damages and the aggregate estimate of overall damages based upon sampling of claims and expert testimony. In the motion, PG&E Corporation and the Utility indicated that they are prepared to agree that, as part of the proposed estimation process, they will not contest causation with respect to any wildfire for which Cal Fire has concluded that PG&E Corporation and the Utility are responsible, including the 2018 Camp fire and the 2017 Northern California wildfires identified above, except the Tubbs fire. The motion is expected to be heard by the Bankruptcy Court on August 14, 2019. On August 7, 2019, certain third parties filed joinders and statements in support with the Bankruptcy Court with respect to PG&E Corporation’s and the Utility’s motion, including the Ad Hoc Noteholder Committee, the UCC and the Shareholder Group. Also on August 7, 2019, certain third parties filed objections to PG&E Corporation’s and the Utility’s motion with the Bankruptcy Court, including the City and County of San Francisco, the Ad Hoc Subrogation Group and the TCC. The objection of the City and County of San Francisco is limited to PG&E Corporation’s and the Utility’s proposal for the Bankruptcy Court to address the legal issue of whether, under the doctrine of inverse condemnation, PG&E Corporation and the Utility may be held strictly liable for wildfire claims asserting property damages even where it was not negligent. Plan Support Agreements with Public Entities On June 18, 2019, PG&E Corporation and the Utility entered into PSAs with certain local public entities providing for an aggregate of $1.0 billion to be paid by PG&E Corporation and the Utility to such public entities pursuant to PG&E Corporation and the Utility’s Chapter 11 plan of reorganization in order to settle such public entities’ claims against PG&E Corporation and the Utility relating to the 2018 Camp fire, 2017 Northern California wildfires and 2015 Butte fire (collectively, “Public Entity Wildfire Claims”). PG&E Corporation and the Utility’s Chapter 11 plan of reorganization currently is under development and has not yet been filed with the Bankruptcy Court. PG&E Corporation and the Utility have entered into a PSA with each of the following public entities or group of public entities, as applicable: • the City of Clearlake, the City of Napa, the City of Santa Rosa, the County of Lake, the Lake County Sanitation District, the County of Mendocino, Napa County, the County of Nevada, the County of Sonoma, the Sonoma County Agricultural Preservation and Open Space District, the Sonoma County Community Development Commission, the Sonoma County Water Agency, the Sonoma Valley County Sanitation District and the County of Yuba (collectively, the “2017 Northern California Wildfire Public Entities”); • the Town of Paradise; • the County of Butte; • the Paradise Recreation & Park District; • the County of Yuba; and • the Calaveras County Water District. For purposes of each PSA, the local public entities that are party to such PSA are referred to herein as “Supporting Public Entities.” Each PSA provides that PG&E Corporation and the Utility’s Chapter 11 plan of reorganization will include, among other things, the following elements: • following the effective date of PG&E Corporation and the Utility’s Chapter 11 plan of reorganization, PG&E Corporation and the Utility will remit a Settlement Amount (as defined below) in the amount set forth below to the applicable Supporting Public Entities in full and final satisfaction and discharge of their Public Entity Wildfire Claims, and • subject to the Supporting Public Entities voting affirmatively to accept PG&E Corporation and the Utility’s Chapter 11 plan of reorganization, following the effective date of PG&E Corporation and the Utility’s Chapter 11 plan of reorganization, PG&E Corporation and the Utility will create and promptly fund $10.0 million to a segregated fund to be used by the Supporting Public Entities collectively in connection with the defense or resolution of claims against the Supporting Public Entities by

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	6 Months Ended
	Jun. 30, 2019
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS On July 12, 2019, the California Governor signed into law AB 1054, a bill which provides for the establishment of a statewide fund that will be available for eligible electric utility companies to pay eligible claims for liabilities arising from wildfires occurring after July 12, 2019 that are caused by the applicable electric utility company’s equipment, subject to the terms and conditions of AB 1054. Eligible claims are claims for third party damages resulting from any such wildfires, limited to the portion of such claims that exceeds the greater of (i) $1.0 billion in the aggregate in any calendar year and (ii) the amount of insurance coverage required to be in place for the electric utility company pursuant to Section 3293 of the Public Utilities Code, added by AB 1054. Each of California’s large investor-owned electric utility companies that are not currently subject to Chapter 11 (Southern California Edison and San Diego Gas & Electric Company) has elected to participate in the Wildfire Fund to be established under AB 1054. On July 23, 2019, the Utility notified the CPUC of its intent to participate in the Wildfire Fund (which participation is subject to the conditions set forth in AB 1054, including those conditions outlined below). The Wildfire Fund to be established under AB 1054 will be available for eligible electric utility companies to pay eligible claims for liabilities arising from wildfires occurring after July 12, 2019 that are caused by the applicable electric utility company’s equipment. Electric utility companies that draw from the fund will only be required to repay amounts that are determined by the CPUC in an application for cost recovery not to be just and reasonable, subject to a rolling three-year disallowance cap equal to 20% of the electric utility company’s transmission and distribution equity rate base. For the Utility, this disallowance cap is expected to be approximately $2.3 billion for the three-year period starting in 2019, subject to adjustment based on changes in the Utility’s total transmission and distribution equity rate base. The disallowance cap is inapplicable in certain circumstances, including if the Wildfire Fund administrator determines that the electric utility company’s actions or inactions that resulted in the applicable wildfire constituted “conscious or willful disregard for the rights and safety of others,” or the electric utility company fails to maintain a valid safety certification. Costs that the CPUC determines to be just and reasonable will not need to be repaid to the fund, resulting in a draw-down of the fund. The Wildfire Fund and disallowance cap will be terminated when the amounts therein are exhausted. The Wildfire Fund is expected to be capitalized with (i) $10.5 billion of proceeds of bonds supported by a 15-year extension of the Department of Water Resources charge to ratepayers, (ii) $7.5 billion in initial contributions from California’s three investor-owned electric utility companies and (iii) $300 million in annual contributions paid by California’s three investor-owned electric utility companies. The contributions from the investor-owned electric utility companies will be effectively borne by their respective shareholders, as they will not be permitted to recover these costs from ratepayers. The costs of the initial and annual contributions are allocated among the three investor-owned electric utility companies pursuant to a “Wildfire Fund allocation metric” set forth in AB 1054 based on land area in the applicable utility’s service territory classified as high fire threat districts and adjusted to account for risk mitigation efforts. The Utility’s initial Wildfire Fund allocation metric is expected to be 64.2% (representing an initial contribution of approximately $4.8 billion and annual contributions of approximately $193 million ). In addition, all initial and annual contributions will be excluded from the measurement of the Utility’s authorized capital structure. AB 1054 provides that the Wildfire Fund will be established when Southern California Edison and San Diego Gas & Electric Company provide their initial contributions. In order to participate in the Wildfire Fund, within 60 days of the effective date of AB 1054, the Utility must obtain the Bankruptcy Court’s approval of the Utility’s election to pay the initial and annual Wildfire Fund contributions upon emergence from Chapter 11. The Utility would then be required to pay its share of the initial contribution to the Wildfire Fund upon emergence from Chapter 11, and meet certain eligibility requirements listed below, in order to participate in the Wildfire Fund. In such event (assuming the Utility satisfies the eligibility and other requirements set forth in AB 1054), the Wildfire Fund will be available to the Utility to pay for eligible claims arising between the effective date of AB 1054 and the Utility’s emergence from Chapter 11, subject to a limit of 40% of the amount of such claims. The balance of any such claims would need to be addressed through the Chapter 11 Cases. There are several additional eligibility requirements for the Utility, including that by June 30, 2020, the following conditions are satisfied: • the Utility’s Chapter 11 Case has been resolved pursuant to a plan of reorganization or similar document not subject to a stay; • the Bankruptcy Court has determined that the resolution of the Utility’s Chapter 11 Case provides funding or otherwise provides for the satisfaction of any pre-petition wildfire claims asserted against the Utility in the Chapter 11 Case, in the amounts agreed upon in any settlement agreements, authorized by the Bankruptcy Court through an estimation process or otherwise allowed by the Bankruptcy Court; • the CPUC has approved the Utility’s plan of reorganization and other documents resolving its Chapter 11 Case, including the Utility’s resulting governance structure as being acceptable in light of the Utility’s safety history, criminal probation, recent financial condition and other factors deemed relevant by the CPUC; • the CPUC has determined that the Utility’s plan of reorganization and other documents resolving its Chapter 11 Case are (i) consistent with California’s climate goals as required pursuant to the California Renewables Portfolio Standard Program and related procurement requirements and (ii) neutral, on average, to the Utility’s ratepayers; and • the CPUC has determined that the Utility’s plan of reorganization and other documents resolving its Chapter 11 Case recognize the contributions of ratepayers, if any, and compensate them accordingly through mechanisms approved by the CPUC, which may include sharing of value appreciation. On August 7, 2019, PG&E Corporation and the Utility submitted a motion with the Bankruptcy Court for the entry of an order authorizing PG&E Corporation and the Utility to participate in the Wildfire Fund and to make any initial and annual contributions to the Wildfire Fund upon emergence from Chapter 11. The motion is expected to be heard on August 28, 2019, and objections and other responses are due August 21, 2019. If the Utility satisfies the requirements to participate in the Wildfire Fund, the Utility will be required to fund its initial contribution upon its emergence from Chapter 11. The Utility’s required contributions to the Wildfire Fund will be substantial. Participation in the Wildfire Fund is expected to have a material impact on PG&E Corporation’s and the Utility’s financial condition, results of operations, liquidity and cash flows. The Utility is currently evaluating the accounting and tax treatment of the required initial and annual contributions. The timing and amount of any potential charges associated with shareholder contributions would also depend on various factors, including the final determination of an allocation of contributions among the Utility and California’s other large electric utility companies (San Diego Gas & Electric Company and Southern California Edison Company) and the timing of resolution of the Chapter 11 Cases. The Utility is currently developing a Chapter 11 plan of reorganization that would provide for the financing of such required contributions, but there can be no assurance that PG&E Corporation and the Utility will successfully develop, consummate or implement any such plan, which will ultimately require Bankruptcy Court, creditor and regulatory approval. Further, there can be no assurance that the expected benefits of participating in the Wildfire Fund ultimately outweigh its substantial costs.

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	6 Months Ended
	Jun. 30, 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 as 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 plan 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 June 30, 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 June 30, 2019 , it did not consolidate any of them.
Pension and Other Post-Retirement Benefits	Pension and Other Post-Retirement Benefits PG&E Corporation and the Utility sponsor a non-contributory defined benefit pension plan and cash balance plan. Both plans are included in “Pension Benefits” below. Post-retirement medical and life insurance plans are included in “Other Benefits” below. Non-service costs are reflected in Other income, net on the Condensed Consolidated Statements of Income. Service costs are reflected in Operating and maintenance on the Condensed Consolidated Statements of Income.
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 case, 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. 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 six months ended June 30, 2019 . Cash payments arising from operating leases were $848 million for the six months ended June 30, 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 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 six months ended, June 30, 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 June 30, 2019 , the Utility’s operating leases had a weighted average remaining lease term of 6.1 years and a weighted average discount rate of 6.1% . 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 June 30, 2019 Six Months Ended June 30, 2019 Operating lease fixed cost $ 114 $ 236 Operating lease variable cost 490 799 Total operating lease costs $ 604 $ 1,035 The following table shows the Utility’s future expected operating lease payments: (in millions) June 30, 2019 2019 (1) $ 450 2020 679 2021 623 2022 548 2023 255 Thereafter 692 Total lease payments 3,247 Less imputed interest (594 ) Total $ 2,653 (1) Represents the remaining expected operating lease payments from July 1, 2019 through December 31, 2019. 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 of the guidance on their Condensed Consolidated Financial Statements and related disclosures. Financial Instruments—Credit Losses In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments-Credit Losses (Topic 326), which provides a model, known as the current expected credit loss model, to estimate the expected lifetime credit loss on financial assets, including trade and other receivables, rather than incurred losses over the remaining life of most financial assets measured at amortized cost. The guidance also requires use of an allowance to record estimated credit losses on available-for-sale debt securities. This ASU will be effective for PG&E Corporation and the Utility on January 1, 2020. PG&E Corporation and the Utility are currently evaluating the impact of the guidance on their Condensed Consolidated Financial Statements and related disclosures.
Earnings Per Share
Use of Derivative Instruments	Use of Derivative Instruments The Utility is exposed to commodity price risk as a result of its electricity and natural gas procurement activities. Procurement costs are recovered through customer rates. The Utility uses both derivative and non-derivative contracts to manage volatility in customer rates due to fluctuating commodity prices. Derivatives include contracts, such as power purchase agreements, forwards, futures, swaps, options, and CRRs that are traded either on an exchange or over-the-counter. By order dated April 8, 2019, the Bankruptcy Court authorized the Utility to continue these programs in the ordinary course of business in a manner consistent with its pre-petition practices. Derivatives are presented in the Utility’s Condensed Consolidated Balance Sheets recorded at fair value and on a net basis in accordance with master netting arrangements for each counter-party. The fair value of derivative instruments is further offset by cash collateral paid or received where the right of offset and the intention to offset exist. Price risk management activities that meet the definition of derivatives are recorded at fair value on the Condensed Consolidated Balance Sheets. These instruments are not held for speculative purposes and are subject to certain regulatory requirements. The Utility expects to fully recover in rates all costs related to derivatives under the applicable ratemaking mechanism in place as long as the Utility’s price risk management activities are carried out in accordance with CPUC directives. Therefore, all unrealized gains and losses associated with the change in fair value of these derivatives are deferred and recorded within the Utility’s regulatory assets and liabilities on the Condensed Consolidated Balance Sheets. Net realized gains or losses on commodity derivatives are recorded in the cost of electricity or the cost of natural gas with corresponding increases or decreases to regulatory balancing accounts for recovery from or refund to customers. The Utility elects the normal purchase and sale exception for eligible derivatives. Eligible derivatives are those that require physical delivery in quantities that are expected to be used by the Utility over a reasonable period in the normal course of business, and do not contain pricing provisions unrelated to the commodity delivered. These items are not reflected in the Condensed Consolidated Balance Sheets.
Fair Value Measurements	PG&E Corporation and the Utility measure their cash equivalents, trust assets, and price risk management instruments at fair value. A three-tier fair value hierarchy is established that prioritizes the inputs to valuation methodologies used to measure fair value: • Level 1 – Observable inputs that reflect quoted prices (unadjusted) for identical assets or liabilities in active markets. • Level 2 – Other inputs that are directly or indirectly observable in the marketplace. • Level 3 – Unobservable inputs which are supported by little or no market activities. The fair value hierarchy requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value.
Valuation Techniques	Valuation Techniques The following describes the valuation techniques used to measure the fair value of the assets and liabilities shown in the tables above. There are no restrictions on the terms and conditions upon which the investments may be redeemed. 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 and six months ended June 30, 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.
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)	6 Months Ended
	Jun. 30, 2019
Reorganizations [Abstract]
Schedule of Liabilities Subject to Compromise	The following table presents LSTC as reported in the Condensed Consolidated Balance Sheets at June 30, 2019 : (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Financing debt (2) $ 21,811 $ 650 $ 22,461 Wildfire-related claims (3) 18,012 — 18,012 Trade creditors 1,325 4 1,329 Non-qualified benefit plan 18 125 143 2001 bankruptcy disputed claims 221 — 221 Customer deposits & advances 278 — 278 Other 164 2 166 Total Liabilities Subject to Compromise $ 41,829 $ 781 $ 42,610 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) At June 30, 2019 , PG&E Corporation and the Utility had $650 million and $21,526 million in aggregate principal amount of pre-petition indebtedness, respectively. Utility pre-petition 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 information regarding pre-petition wildfire-related claims reported as LSTC. As described in Note 10 under the heading “Plan Support Agr ee ments with Public Entities,” on June 18, 2019, PG&E Corporation and the Utility entered into agreements with certain local public entities to potentially resolve their wildfire-related claims through the Chapter 11 process.
Schedule of Debtor Reorganization Items	Reorganization items, net for the three months ended June 30, 2019 and from the Petition Date through June 30, 2019 include the following: Three Months Ended June 30, 2019 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ — $ — $ — Legal and other 75 1 76 Interest income (18 ) (3 ) (21 ) Adjustments to LSTC — — — Trustee fees (2) — 1 1 Total reorganization items, net $ 57 $ (1 ) $ 56 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) PG&E Corporation and the Utility incurred $416,667 and $250,000 , respectively, in fees to the U.S. Trustee in the three months ended June 30, 2019. Petition Date Through June 30, 2019 (in millions) Utility PG&E Corporation (1) PG&E Corporation Consolidated Debtor-in-possession financing costs $ 97 $ 17 $ 114 Legal and other 98 2 100 Interest income (27 ) (5 ) (32 ) Adjustments to LSTC — — — Trustee fees (2) — 1 1 Total reorganization items, net $ 168 $ 15 $ 183 (1) PG&E Corporation amounts reflected under the column “PG&E Corporation” exclude the accounts of the Utility. (2) PG&E Corporation and the Utility incurred $416,667 and $250,000 , respectively, in fees to the U.S. Trustee through June 30, 2019.

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	6 Months Ended
	Jun. 30, 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 and six months ended June 30, 2019 and 2018 were as follows: Pension Benefits Other Benefits Three Months Ended June 30, (in millions) 2019 2018 2019 2018 Service cost for benefits earned (1) $ 111 $ 129 $ 14 $ 17 Interest cost 190 172 19 18 Expected return on plan assets (226 ) (256 ) (30 ) (32 ) Amortization of prior service cost (2 ) (2 ) 3 3 Amortization of net actuarial loss — 2 (1 ) (2 ) Net periodic benefit cost 73 45 5 4 Regulatory account transfer (2) 10 39 — — Total $ 83 $ 84 $ 5 $ 4 (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. Pension Benefits Other Benefits Six Months Ended June 30, (in millions) 2019 2018 2019 2018 Service cost for benefits earned (1) $ 222 $ 257 $ 28 $ 33 Interest cost 379 344 38 35 Expected return on plan assets (453 ) (511 ) (61 ) (65 ) Amortization of prior service cost (3 ) (3 ) 7 7 Amortization of net actuarial loss 1 3 (2 ) (3 ) Net periodic benefit cost 146 90 10 7 Regulatory account transfer (2) 21 77 — — Total $ 167 $ 167 $ 10 $ 7 (1) A portion of service costs are capitalized pursuant to ASU 2017-07. (2)
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 June 30, 2019 Beginning balance $ (21 ) $ 17 $ (4 ) Amounts reclassified from other comprehensive income: Amortization of prior service cost (net of taxes of $1 and $1, respectively) (1) (1 ) 2 1 Amortization of net actuarial loss (net of taxes of $0 and $1, respectively) (1) — — — Regulatory account transfer (net of taxes of $1 and $0, respectively) (1) 1 (2 ) (1 ) Net current period other comprehensive gain (loss) — — — Ending balance $ (21 ) $ 17 $ (4 ) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.) Pension Benefits Other Total (in millions, net of income tax) Three Months Ended June 30, 2018 Beginning balance $ (30 ) $ 17 $ (13 ) Amounts reclassified from other comprehensive income: (1) Amortization of prior service cost (net of taxes of $1 and $1, respectively) (1 ) 2 1 Amortization of net actuarial loss (net of taxes of $1 and $1, respectively) 1 (1 ) — Regulatory account transfer (net of taxes of $0 and $0, respectively) — (1 ) (1 ) Net current period other comprehensive gain (loss) — — — 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.) Pension Other Total (in millions, net of income tax) Six Months Ended June 30, 2019 Beginning balance $ (21 ) $ 17 $ (4 ) Amounts reclassified from other comprehensive income: Amortization of prior service cost (net of taxes of $1 and $2, respectively) (1) (2 ) 5 3 Amortization of net actuarial loss (net of taxes of $0 and $1, respectively) (1) 1 (1 ) — Regulatory account transfer (net of taxes of $1 and $1, respectively) (1) 1 (4 ) (3 ) Net current period other comprehensive gain (loss) — — — Ending balance $ (21 ) $ 17 $ (4 ) (1) These components are included in the computation of net periodic pension and other post-retirement benefit costs. (See the “Pension and Other Post-Retirement Benefits” table above for additional details.) Pension Other Total (in millions, net of income tax) Six Months Ended June 30, 2018 Beginning balance $ (25 ) $ 17 $ (8 ) Amounts reclassified from other comprehensive income: Amortization of prior service cost (net of taxes of $1 and $2, respectively) (1) (2 ) 5 3 Amortization of net actuarial loss (net of taxes of $1 and $1, respectively) (1) 2 (2 ) — Regulatory account transfer (net of taxes of $0 and $1, respectively) (1) — (3 ) (3 ) Reclassification of stranded income tax to retained earnings (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 June 30, Six Months Ended June 30, (in millions) 2019 2018 2019 2018 Electric Revenue from contracts with customers Residential $ 994 $ 1,039 $ 2,282 $ 2,375 Commercial 1,135 1,234 2,088 2,307 Industrial 326 354 619 678 Agricultural 261 318 347 443 Public street and highway lighting 16 18 33 38 Other (1) — 84 (309 ) (118 ) Total revenue from contracts with customers - electric 2,732 3,047 5,060 5,723 Regulatory balancing accounts (2) 214 265 678 540 Total electric operating revenue $ 2,946 $ 3,312 $ 5,738 $ 6,263 Natural gas Revenue from contracts with customers Residential $ 343 $ 452 $ 1,515 $ 1,410 Commercial 129 119 369 315 Transportation service only 304 264 686 560 Other (1) (129 ) (128 ) (205 ) (179 ) Total revenue from contracts with customers - gas 647 707 2,365 2,106 Regulatory balancing accounts (2) 350 215 (149 ) (79 ) Total natural gas operating revenue 997 922 2,216 2,027 Total operating revenues $ 3,943 $ 4,234 $ 7,954 $ 8,290 (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 June 30, 2019 Six Months Ended June 30, 2019 Operating lease fixed cost $ 114 $ 236 Operating lease variable cost 490 799 Total operating lease costs $ 604 $ 1,035
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) June 30, 2019 2019 (1) $ 450 2020 679 2021 623 2022 548 2023 255 Thereafter 692 Total lease payments 3,247 Less imputed interest (594 ) Total $ 2,653 (1) Represents the remaining expected operating lease payments from July 1, 2019 through December 31, 2019. 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)	6 Months Ended
	Jun. 30, 2019
Regulated Operations [Abstract]
Long-Term Regulatory Assets	Long-term regulatory assets are comprised of the following: Asset Balance at (in millions) June 30, 2019 December 31, 2018 Pension benefits (1) $ 1,928 $ 1,947 Environmental compliance costs 997 1,013 Utility retained generation (2) 251 274 Price risk management 67 90 Unamortized loss, net of gain, on reacquired debt (3) 230 76 Catastrophic event memorandum account (4) 918 790 Wildfire expense memorandum account (5) 127 94 Fire hazard prevention memorandum account (6) 291 263 Fire risk mitigation memorandum account (7) 154 — Other 386 417 Total long-term regulatory assets $ 5,349 $ 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. (7) Includes costs associated with the 2019 Wildfire Safety Plan. 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) June 30, 2019 December 31, 2018 Cost of removal obligations (1) $ 6,233 $ 5,981 Deferred income taxes (2) 4 283 Recoveries in excess of AROs (3) 472 356 Public purpose programs (4) 785 674 Employee benefit plans (5) 423 421 Other 1,121 824 Total long-term regulatory liabilities $ 9,038 $ 8,539 (1) Represents the cumulative differences between the recorded costs to remove assets and amounts collected in rates for expected costs to remove assets. (2) Represents the 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) June 30, 2019 December 31, 2018 Electric distribution $ 465 $ 160 Electric transmission 91 128 Utility generation 92 79 Gas distribution and transmission 173 462 Energy procurement 654 168 Public purpose programs 97 111 Other 312 327 Total regulatory balancing accounts receivable $ 1,884 $ 1,435
Regulatory Balancing Accounts Payable	Payable Balance at (in millions) June 30, 2019 December 31, 2018 Electric transmission 135 134 Gas distribution and transmission 6 9 Energy procurement 308 59 Public purpose programs 610 587 Other 311 287 Total regulatory balancing accounts payable $ 1,370 $ 1,076

DEBT (Tables)

DEBT (Tables)	6 Months Ended
	Jun. 30, 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 June 30, 2019 : (in millions) Termination Date Aggregate Limit Term Loan Borrowings Revolver Borrowings Letters of Credit Outstanding Aggregate Availability DIP Facilities December 2020 (1) $ 5,500 $ 1,500 $ — $ 521 $ 3,479 (1) May be extended to December 2021, subject to satisfaction of certain terms and conditions, including payment of a 25 basis point extension fee.
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 June 30, 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 2047 2.95% to 6.35% 14,600 14,600 Unamortized discount, net of 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) Debt subject to compromise must be reported at the amounts expected to be allowed by the Bankruptcy Court and the carrying values will be adjusted as claims are approved. Total Utility Debt Subject to Compromise does not include $285 million of accrued contractual interest to the Petition Date. At 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 Balance Sheets. See Notes 2 and 4 for further details. (2) At June 30, 2019 , the contractual LIBOR-based interest rate on loans was 3.87% . (3) At June 30, 2019 , the contractual LIBOR-based interest rate on the term loan was 3.60% . (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 matured on June 5, 2019. In December 2015, the maturity dates of the letter of credit facilities supporting the Series 1996 C, E, F, 1997 B bonds were extended to December 1, 2020. Although the stated maturity date of these bonds is 2026, each series will remain outstanding only if the Utility extends or replaces the letter of credit related to the series or otherwise obtains consent from the issuer to the continuation of the series without a credit facility. (6) At June 30, 2019 , the contractual interest rate on the letter of credit facility supporting these bonds was 7.70% . (7) At June 30, 2019 , the contractual interest rate on the letter of credit facility supporting these bonds ranged from 7.70% to 7.83% . (8) Also includes $79 million in letters of credit. (9) At June 30, 2019 , the contractual LIBOR-based interest rate on the loans was 3.67% . (10) At June 30, 2019 , the contractual LIBOR-based interest rate on the term loan was 3.00% .

EARNINGS PER SHARE (Tables)

EARNINGS PER SHARE (Tables)	6 Months Ended
	Jun. 30, 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 June 30, Six Months Ended June 30, (in millions, except per share amounts) 2019 2018 2019 2018 Loss attributable to common shareholders $ (2,553 ) $ (984 ) $ (2,420 ) $ (542 ) Weighted average common shares outstanding, basic 529 516 528 516 Add incremental shares from assumed conversions: Employee share-based compensation — — — 1 Weighted average common shares outstanding, diluted 529 516 528 517 Total loss per common share, diluted $ (4.83 ) $ (1.91 ) $ (4.58 ) $ (1.05 )

DERIVATIVES (Tables)

DERIVATIVES (Tables)	6 Months Ended
	Jun. 30, 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 June 30, December 31, Natural Gas (1) (MMBtus (2) ) Forwards, Futures and Swaps 174,575,917 177,750,349 Options 16,455,000 13,735,405 Electricity (Megawatt-hours) Forwards, Futures and Swaps 2,999,616 3,833,490 Options 912,033 — Congestion Revenue Rights (3) 329,571,344 340,783,089 (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 June 30, 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 $ 47 $ (4 ) $ 48 $ 91 Other noncurrent assets – other 161 — — 161 Current liabilities – other (25 ) 4 3 (18 ) Noncurrent liabilities – other (67 ) — — (67 ) Total commodity risk $ 116 $ — $ 51 $ 167 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 June 30, 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 $ 47 $ (4 ) $ 48 $ 91 Other noncurrent assets – other 161 — — 161 Current liabilities – other (25 ) 4 3 (18 ) Noncurrent liabilities – other (67 ) — — (67 ) Total commodity risk $ 116 $ — $ 51 $ 167 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)	6 Months Ended
	Jun. 30, 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 June 30, 2019 (in millions) Level 1 Level 2 Level 3 Netting (1) Total Assets: Short-term investments $ 3,402 $ — $ — $ — $ 3,402 Nuclear decommissioning trusts Short-term investments 16 — — — 16 Global equity securities 1,959 — — — 1,959 Fixed-income securities 815 698 — — 1,513 Assets measured at NAV — — — — 19 Total nuclear decommissioning trusts (2) 2,790 698 — — 3,507 Price risk management instruments (Note 8) Electricity — 13 192 20 225 Gas — 3 — 24 27 Total price risk management instruments — 16 192 44 252 Rabbi trusts Fixed-income securities — 98 — — 98 Life insurance contracts — 71 — — 71 Total rabbi trusts — 169 — — 169 Long-term disability trust Short-term investments 5 — — — 5 Assets measured at NAV — — — — 142 Total long-term disability trust 5 — — — 147 TOTAL ASSETS $ 6,197 $ 883 $ 192 $ 44 $ 7,477 Liabilities: Price risk management instruments (Note 8) Electricity $ — $ 4 $ 83 $ (4 ) $ 83 Gas 2 3 — (3 ) 2 TOTAL LIABILITIES $ 2 $ 7 $ 83 $ (7 ) $ 85 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and margin cash collateral. (2) Represents amount before deducting $491 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) June 30, 2019 Fair Value Measurement Assets Liabilities Valuation Unobservable Range (1) Congestion revenue rights $ 191 $ 64 Market approach CRR auction prices $(13.11) - 22.76 Power purchase agreements $ 1 $ 19 Discounted cash flow Forward prices $ 19.68 - 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 and six months ended June 30, 2019 and 2018 : Price Risk Management Instruments (in millions) 2019 2018 Asset (liability) balance as of April 1 $ 129 $ 40 Net realized and unrealized gains: Included in regulatory assets and liabilities or balancing accounts (1) (20 ) (6 ) Asset (liability) balance as of June 30 $ 109 $ 34 (1) The costs related to price risk management activities are fully passed through to customers in rates. Accordingly, unrealized gains and losses are deferred in regulatory liabilities and assets and net income is not impacted. Price Risk Management Instruments (in millions) 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) 14 (8 ) Asset (liability) balance as of June 30 $ 109 $ 34 (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 June 30, 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) 1,500 1,500 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 June 30, 2019 Amortized Total Unrealized Gains Total Unrealized Losses Total Fair Nuclear decommissioning trusts Short-term investments $ 16 $ — $ — $ 16 Global equity securities 496 1,486 (4 ) 1,978 Fixed-income securities 1,431 84 (2 ) 1,513 Total (1) $ 1,943 $ 1,570 $ (6 ) $ 3,507 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 $491 million and $408 million for the periods ended June 30, 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) June 30, 2019 Less than 1 year $ 26 1–5 years 541 5–10 years 340 More than 10 years 606 Total maturities of fixed-income securities $ 1,513
Schedule of Activity for Debt and Equity Securities	The following table provides a summary of activity for fixed income and equity securities: Three Months Ended June 30, Six Months Ended June 30, (in millions) 2019 2018 2019 2018 Proceeds from sales and maturities of nuclear decommissioning trust investments $ 171 $ 308 $ 517 $ 802 Gross realized gains on securities 56 11 22 48 Gross realized losses on securities (26 ) (5 ) (7 ) (9 )

WILDFIRE-RELATED CONTINGENCIES

WILDFIRE-RELATED CONTINGENCIES (Tables)	6 Months Ended
	Jun. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Schedule of Environmental Remediation Liability	At June 30, 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) June 30, 2019 December 31, 2018 2015 Butte fire $ 212 $ 226 2017 Northern California wildfires 5,500 3,500 2018 Camp fire 12,400 10,500 Total wildfire-related claims (1) $ 18,112 $ 14,226 (1) On the Petition Date, all wildfire-related claims were classified as LSTC and all pending litigation was stayed. As of June 30, 2019, $ 100 million was reclassified from LSTC to current liabilities - wildfire-related claims to reflect Bankruptcy Court approval of contributions to the Wildfire Assistance Fund.
Change in Accruals Related to Third-Party Claims	The following table presents changes in the insurance receivable for the six months ended June 30, 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 June 30, 2019 $ 1,380 2017 Northern California wildfires Balance at December 31, 2018 $ 829 Accrued insurance recoveries — Reimbursements — Balance at June 30, 2019 $ 829

OTHER CONTINGENCIES AND COMMI_2

OTHER CONTINGENCIES AND COMMITMENTS (Tables)	6 Months Ended
	Jun. 30, 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 (in millions) June 30, 2019 December 31, 2018 Topock natural gas compressor station $ 346 $ 369 Hinkley natural gas compressor station 142 146 Former manufactured gas plant sites owned by the Utility or third parties (1) 580 520 Utility-owned generation facilities (other than fossil fuel-fired), (2) 112 111 Fossil fuel-fired generation facilities and sites (3) 125 137 Total environmental remediation liability $ 1,305 $ 1,283 (1) Primarily driven by the following sites: Vallejo, San Francisco East Harbor, Napa, Beach Street, San Francisco North Beach, and San Rafael MGP-Bio Marin MGP. (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 (Details)	6 Months Ended
	Jun. 30, 2019segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of operating segments (segment)	1

BANKRUPTCY FILING (Narrative) (

BANKRUPTCY FILING (Narrative) (Details)	5 Months Ended	6 Months Ended
	Jun. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Jul. 17, 2019unit	Feb. 01, 2019USD ($)	Jan. 31, 2019USD ($)
Debt Instrument [Line Items]
Contractual interest expense on prepetition liabilities not recorded in financial statements	$ 405,000,000
DIP Credit Agreement | Line of Credit | Senior Secured Superpriority Debt
Debt Instrument [Line Items]
Amount arranged	$ 5,500,000,000	$ 5,500,000,000		$ 5,500,000,000	$ 5,500,000,000
Pacific Gas & Electric Co
Debt Instrument [Line Items]
Payments for reorganization items		78,000,000
PG&E Corporation
Debt Instrument [Line Items]
Payments for reorganization items		$ 15,000,000
Subsequent Event | Pacific Gas & Electric Co
Debt Instrument [Line Items]
Number of collective bargaining units (unit) | unit			2

BANKRUPTCY FILING (Schedule of

BANKRUPTCY FILING (Schedule of Liabilities Subject to Compromise) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Reorganizations [Line Items]
Financing debt	$ 22,461
Wildfire-related claims	18,012
Trade creditors	1,329
Non-qualified benefit plan	143
2001 bankruptcy disputed claims	221
Customer deposits & advances	278
Other	166
Total Liabilities Subject to Compromise	42,610	$ 0
Pacific Gas & Electric Co
Reorganizations [Line Items]
Financing debt	21,811
Wildfire-related claims	18,012
Trade creditors	1,325
Non-qualified benefit plan	18
2001 bankruptcy disputed claims	221
Customer deposits & advances	278
Other	164
Total Liabilities Subject to Compromise	41,829	$ 0
Aggregate principal amount of debt subject to compromise	21,526
Accrued contractual interest subject to compromise	285
PG&E Corporation
Reorganizations [Line Items]
Financing debt	650
Wildfire-related claims	0
Trade creditors	4
Non-qualified benefit plan	125
2001 bankruptcy disputed claims	0
Customer deposits & advances	0
Other	2
Total Liabilities Subject to Compromise	781
Aggregate principal amount of debt subject to compromise	$ 650

SUMMARY OF SIGNIFICANT ACCOUN_4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Components of Net Periodic Benefit Cost) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	$ 111	$ 129	$ 222	$ 257
Interest cost	190	172	379	344
Expected return on plan assets	(226)	(256)	(453)	(511)
Amortization of prior service cost	(2)	(2)	(3)	(3)
Amortization of net actuarial loss	0	2	1	3
Net periodic benefit cost	73	45	146	90
Regulatory account transfer	10	39	21	77
Total	83	84	167	167
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost for benefits earned	14	17	28	33
Interest cost	19	18	38	35
Expected return on plan assets	(30)	(32)	(61)	(65)
Amortization of prior service cost	3	3	7	7
Amortization of net actuarial loss	(1)	(2)	(2)	(3)
Net periodic benefit cost	5	4	10	7
Regulatory account transfer	0	0	0	0
Total	$ 5	$ 4	$ 10	$ 7

BANKRUPTCY FILING (Schedule o_2

BANKRUPTCY FILING (Schedule of Debtor Reorganization Items) (Details) - USD ($)	3 Months Ended		5 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2019	Jun. 30, 2018
Reorganizations [Line Items]
Debtor-in-possession financing costs	$ 0		$ 114,000,000
Legal and other	76,000,000		100,000,000
Interest income	(21,000,000)		(32,000,000)
Adjustments to LSTC	0		0
Trustee fees	1,000,000		1,000,000
Total reorganization items, net	56,000,000	$ 0	183,000,000	$ 183,000,000	$ 0
PG&E Corporation
Reorganizations [Line Items]
Debtor-in-possession financing costs	0		17,000,000
Legal and other	1,000,000		2,000,000
Interest income	(3,000,000)		(5,000,000)
Adjustments to LSTC	0		0
Trustee fees	1,000,000		1,000,000
Total reorganization items, net	(1,000,000)		15,000,000
Fees paid to the U.S. Trustee	416,667		416,667
Utility
Reorganizations [Line Items]
Debtor-in-possession financing costs	0		97,000,000
Legal and other	75,000,000		98,000,000
Interest income	(18,000,000)		(27,000,000)
Adjustments to LSTC	0		0
Trustee fees	0		0
Total reorganization items, net	57,000,000	$ 0	168,000,000	$ 168,000,000	$ 0
Fees paid to the U.S. Trustee	$ 250,000		$ 250,000

SUMMARY OF SIGNIFICANT ACCOUN_5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Reclassifications Out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	$ 13,129		$ 12,903	$ 19,472
Net current period other comprehensive gain (loss)	0	$ 0	0	(5)
Ending balance	10,594	19,061	10,594	19,061
Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Net current period other comprehensive gain (loss)	0	0	0	(5)
Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Net current period other comprehensive gain (loss)	0	0	0	0
Accumulated Other Comprehensive Income (Loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(4)	(13)	(4)	(8)
Ending balance	(4)	(13)	(4)	(13)
Accumulated Other Comprehensive Income (Loss) | Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(21)	(30)	(21)	(25)
Ending balance	(21)	(30)	(21)	(30)
Accumulated Other Comprehensive Income (Loss) | Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	17	17	17	17
Ending balance	17	17	17	17
Amortization of prior service cost
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	1	1	3	3
Amortization of prior service cost | Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(1)	(1)	(2)	(2)
Amount attributable to tax	1	1	1	1
Amortization of prior service cost | Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	2	2	5	5
Amount attributable to tax	1	1	2	2
Amortization of net actuarial loss
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	0	0	0	0
Amortization of net actuarial loss | Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	0	1	1	2
Amount attributable to tax	0	1	0	1
Amortization of net actuarial loss | Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	0	(1)	(1)	(2)
Amount attributable to tax	1	1	1	1
Regulatory account transfer
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(1)	(1)	(3)	(3)
Regulatory account transfer | Pension Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	1	0	1	0
Amount attributable to tax	1	0	1	0
Regulatory account transfer | Other Benefits
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from other comprehensive income	(2)	(1)	(4)	(3)
Amount attributable to tax	$ 0	$ 0	$ 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)
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

SUMMARY OF SIGNIFICANT ACCOUN_6

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Narrative) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jan. 01, 2019
Lessee, Lease, Description [Line Items]
Period for probable revenue recovery	24 months
Cash payments arising from operating leases	$ 848
ROU assets	2,662
Lease liabilities	$ 2,653
Weighted average remaining lease term	6 years 1 month 13 days
Weighted average discount rate	6.10%
Minimum
Lessee, Lease, Description [Line Items]
Power purchase agreement, term	5 years
Maximum
Lessee, Lease, Description [Line Items]
Power purchase agreement, term	20 years
Accounting Standards Update 2016-02
Lessee, Lease, Description [Line Items]
ROU assets		$ 2,800
Lease liabilities		$ 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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Revenue from contracts with customers
Total operating revenues	$ 3,943	$ 4,234	$ 7,954	$ 8,290
Electric
Revenue from contracts with customers
Total revenue from contracts with customers	2,732	3,047	5,060	5,723
Regulatory balancing accounts	214	265	678	540
Total operating revenues	2,946	3,312	5,738	6,263
Electric | Residential
Revenue from contracts with customers
Total revenue from contracts with customers	994	1,039	2,282	2,375
Electric | Commercial
Revenue from contracts with customers
Total revenue from contracts with customers	1,135	1,234	2,088	2,307
Electric | Industrial
Revenue from contracts with customers
Total revenue from contracts with customers	326	354	619	678
Electric | Agricultural
Revenue from contracts with customers
Total revenue from contracts with customers	261	318	347	443
Electric | Public street and highway lighting
Revenue from contracts with customers
Total revenue from contracts with customers	16	18	33	38
Electric | Other
Revenue from contracts with customers
Total revenue from contracts with customers	0	84	(309)	(118)
Natural gas
Revenue from contracts with customers
Total revenue from contracts with customers	647	707	2,365	2,106
Regulatory balancing accounts	350	215	(149)	(79)
Total operating revenues	997	922	2,216	2,027
Natural gas | Residential
Revenue from contracts with customers
Total revenue from contracts with customers	343	452	1,515	1,410
Natural gas | Commercial
Revenue from contracts with customers
Total revenue from contracts with customers	129	119	369	315
Natural gas | Transportation service only
Revenue from contracts with customers
Total revenue from contracts with customers	304	264	686	560
Natural gas | Other
Revenue from contracts with customers
Total revenue from contracts with customers	$ (129)	$ (128)	$ (205)	$ (179)

SUMMARY OF SIGNIFICANT ACCOUN_8

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Schedule of Lease Expense) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019
Accounting Policies [Abstract]
Operating lease fixed cost	$ 114	$ 236
Operating lease variable cost	490	799
Total operating lease costs	$ 604	$ 1,035

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	Jun. 30, 2019	Dec. 31, 2018
Future Expected Operating Lease Payments
2019	$ 450
2020	679
2021	623
2022	548
2023	255
Thereafter	692
Total lease payments	3,247
Less imputed interest	(594)
Total	$ 2,653
Future Expected Obligations and Other 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	Jun. 30, 2019	Dec. 31, 2018
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 5,349	$ 4,964
Retained generation asset costs	1,200
Pension benefits
Regulatory Assets [Line Items]
Total long-term regulatory assets	1,928	1,947
Environmental compliance costs
Regulatory Assets [Line Items]
Total long-term regulatory assets	997	1,013
Utility retained generation
Regulatory Assets [Line Items]
Total long-term regulatory assets	251	274
Price risk management
Regulatory Assets [Line Items]
Total long-term regulatory assets	67	90
Unamortized loss, net of gain, on reacquired debt
Regulatory Assets [Line Items]
Total long-term regulatory assets	230	76
Catastrophic event memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	918	790
Wildfire expense memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	127	94
Fire hazard prevention memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	291	263
Fire risk mitigation memorandum account
Regulatory Assets [Line Items]
Total long-term regulatory assets	154	0
Other
Regulatory Assets [Line Items]
Total long-term regulatory assets	$ 386	$ 417

REGULATORY ASSETS, LIABILITIE_4

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Long-Term Regulatory Liabilities) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 9,038	$ 8,539
Cost of removal obligations
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	6,233	5,981
Deferred income taxes
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	4	283
Recoveries in excess of AROs
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	472	356
Public purpose programs
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	785	674
Employee benefit plans
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	423	421
Other
Regulatory Liabilities [Line Items]
Total long-term regulatory liabilities	$ 1,121	$ 824

REGULATORY ASSETS, LIABILITIE_5

REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS (Current Regulatory Balancing Accounts, Net) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Total regulatory balancing accounts receivable
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	$ 1,884	$ 1,435
Total regulatory balancing accounts receivable | Electric distribution
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	465	160
Total regulatory balancing accounts receivable | Electric transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	91	128
Total regulatory balancing accounts receivable | Utility generation
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	92	79
Total regulatory balancing accounts receivable | Gas distribution and transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	173	462
Total regulatory balancing accounts receivable | Energy procurement
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	654	168
Total regulatory balancing accounts receivable | Public purpose programs
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	97	111
Total regulatory balancing accounts receivable | Other
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	312	327
Total regulatory balancing accounts payable
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	1,370	1,076
Total regulatory balancing accounts payable | Electric transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	135	134
Total regulatory balancing accounts payable | Gas distribution and transmission
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	6	9
Total regulatory balancing accounts payable | Energy procurement
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	308	59
Total regulatory balancing accounts payable | Public purpose programs
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	610	587
Total regulatory balancing accounts payable | Other
Regulatory Assets [Line Items]
Total regulatory balancing accounts, net	$ 311	$ 287

DEBT (Debtor In Possession ("DI

DEBT (Debtor In Possession ("DIP") Facilities and Financing) (Details)	Jun. 30, 2019USD ($)	Apr. 03, 2019USD ($)	Mar. 27, 2019USD ($)	Feb. 01, 2019USD ($)	Jan. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Line of Credit Facility [Line Items]
Debtor-in-possession financing	$ 1,500,000,000					$ 0
Commercial Paper	0
Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Debtor-in-possession financing	1,500,000,000					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	$ 5,500,000,000
DIP Revolving Facility | Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Revolver Borrowings	2,965,000,000					$ 2,965,000,000
Letters of Credit Outstanding	79,000,000
DIP Revolving Facility | DIP Credit Agreement | Pacific Gas & Electric Co
Line of Credit Facility [Line Items]
Aggregate Limit	5,500,000,000
Term Loan Borrowings	1,500,000,000
Revolver Borrowings	0
Letters of Credit Outstanding	521,000,000
Aggregate Availability	$ 3,479,000,000
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 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
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
Repayments of debt		$ 350,000,000
DIP Incremental Facilities | Line of Credit | DIP Credit Agreement
Line of Credit Facility [Line Items]
Amount arranged				$ 4,000,000,000

DEBT (Schedule of Long-term Deb

DEBT (Schedule of Long-term Debt) (Details) - USD ($) $ in Millions	Mar. 31, 2019	Jun. 30, 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
Borrowings under Pre-Petition Credit Facility		3,215	3,215
Pollution control bonds		863	863
Accrued contractual interest subject to compromise		285
PG&E Corporation
Debt [Line Items]
Debt subject to compromise		650	650
Term Loan - Stated Maturity: 2020 | PG&E Corporation
Debt [Line Items]
Debt subject to compromise		$ 350	350
Interest rate at period end		3.60%
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, 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, due 2026 | Pacific Gas & Electric Co
Debt [Line Items]
Pollution control bonds		149	149
Pollution Control Bonds - Series 1996 C, E, F, 1997 B due 2026 | Pacific Gas & Electric Co
Debt [Line Items]
Pollution control bonds		614	614
Term Loan - Stated Maturity: 2019 | Pacific Gas & Electric Co
Debt [Line Items]
Other borrowings		$ 250	250
Interest rate at period end		3.00%
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		$ 79
Line of Credit | Revolving Credit Facility | PG&E Corporation
Debt [Line Items]
Debt subject to compromise		$ 300	300
Interest rate at period end		3.87%
Senior Notes | Pacific Gas & Electric Co
Debt [Line Items]
Unamortized discount, net of premium and debt issuance costs		$ 0	(178)
Borrowings under Pre-Petition Credit Facility		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 2047 | Pacific Gas & Electric Co
Debt [Line Items]
Senior notes		$ 14,600	$ 14,600
Senior Notes | Senior Notes Due 2024 through 2047 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Contractual Interest Rates		2.95%
Senior Notes | Senior Notes Due 2024 through 2047 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Contractual Interest Rates		6.35%
Letter of Credit | Pollution Control Bonds - Series 2009 A-B, due 2026 | Pacific Gas & Electric Co
Debt [Line Items]
Interest rate at period end		7.70%
Letter of Credit | Pollution Control Bonds - Series 1996 C, E, F, 1997 B due 2026 | Pacific Gas & Electric Co | Minimum
Debt [Line Items]
Interest rate at period end		7.70%
Letter of Credit | Pollution Control Bonds - Series 1996 C, E, F, 1997 B due 2026 | Pacific Gas & Electric Co | Maximum
Debt [Line Items]
Interest rate at period end		7.83%

EQUITY (Details)

EQUITY (Details) - 401K Plan and Shared Based Compensation Plans shares in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2019USD ($)shares
Schedule Of Changes In Equity [Line Items]
Stock issued during period (in shares) | shares	8.9
Cash proceeds from stock issuance | $	$ 85

EARNINGS PER SHARE (Details)

EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Earnings Per Share [Abstract]
Loss attributable to common shareholders	$ (2,553)	$ (984)	$ (2,420)	$ (542)
Weighted average common shares outstanding, basic (in shares)	529	516	528	516
Add incremental shares from assumed conversions:
Employee share-based compensation (in shares)	0	0	0	1
Weighted average common shares outstanding, diluted (in shares)	529	516	528	517
Total loss per common share, diluted (in dollars per share)	$ (4.83)	$ (1.91)	$ (4.58)	$ (1.05)

DERIVATIVES (Volumes of Outstan

DERIVATIVES (Volumes of Outstanding Derivative Contracts, in Megawatt Hours Unless Otherwise Specified) (Details)	Jun. 30, 2019MWhMMBTU	Dec. 31, 2018MWhMMBTU
Forwards, Futures and Swaps | Natural Gas
Derivative [Line Items]
Contract Volume (mmbtu and mwh) | MMBTU	174,575,917	177,750,349
Forwards, Futures and Swaps | Electricity
Derivative [Line Items]
Contract Volume (mmbtu and mwh)	2,999,616	3,833,490
Options | Natural Gas
Derivative [Line Items]
Contract Volume (mmbtu and mwh) | MMBTU	16,455,000	13,735,405
Options | Electricity
Derivative [Line Items]
Contract Volume (mmbtu and mwh)	912,033	0
Congestion Revenue Rights | Electricity
Derivative [Line Items]
Contract Volume (mmbtu and mwh)	329,571,344	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	Jun. 30, 2019	Dec. 31, 2018
Assets:
Short-term investments	$ 3,402	$ 1,593
Price risk management instruments, netting	44	88
Price risk management instruments, assets	252	297
TOTAL ASSETS	7,477	5,350
Liabilities:
Price risk management instruments, netting	(7)	(10)
TOTAL LIABILITIES	85	109
Amount primarily related to deferred taxes on appreciation of investment value	491	408
Nuclear decommissioning trusts
Assets:
Short-term investments	16	29
Global equity securities	1,959	1,793
Fixed-income securities	1,513	1,300
TOTAL ASSETS	3,507	3,138
Rabbi trusts
Assets:
Fixed-income securities	98	93
Life insurance contracts	71	67
TOTAL ASSETS	169	160
Long-term disability trust
Assets:
Short-term investments	5	7
TOTAL ASSETS	147	162
Price Risk Derivative, Electricity
Assets:
Price risk management instruments, netting	20	51
Price risk management instruments, assets	225	259
Liabilities:
Price risk management instruments, netting	(4)	(10)
Price risk management instruments, liabilities	83	107
Price Risk Derivative, Gas
Assets:
Price risk management instruments, netting	24	37
Price risk management instruments, assets	27	38
Liabilities:
Price risk management instruments, netting	(3)	0
Price risk management instruments, liabilities	2	2
Level 1
Assets:
Short-term investments	3,402	1,593
Price risk management instruments, gross subject to netting	0	0
TOTAL ASSETS	6,197	4,083
Liabilities:
TOTAL LIABILITIES	2	4
Level 1 | Nuclear decommissioning trusts
Assets:
Short-term investments	16	29
Global equity securities	1,959	1,793
Fixed-income securities	815	661
TOTAL ASSETS	2,790	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	5	7
TOTAL ASSETS	5	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	0	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	2	0
Level 2
Assets:
Short-term investments	0	0
Price risk management instruments, gross subject to netting	16	6
TOTAL ASSETS	883	805
Liabilities:
TOTAL LIABILITIES	7	7
Level 2 | Nuclear decommissioning trusts
Assets:
Short-term investments	0	0
Global equity securities	0	0
Fixed-income securities	698	639
TOTAL ASSETS	698	639
Level 2 | Rabbi trusts
Assets:
Fixed-income securities	98	93
Life insurance contracts	71	67
TOTAL ASSETS	169	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	13	5
Liabilities:
Price risk management instruments, gross subject to netting	4	5
Level 2 | Price Risk Derivative, Gas
Assets:
Price risk management instruments, gross subject to netting	3	1
Liabilities:
Price risk management instruments, gross subject to netting	3	2
Level 3
Assets:
Short-term investments	0	0
Price risk management instruments, gross subject to netting	192	203
TOTAL ASSETS	192	203
Liabilities:
TOTAL LIABILITIES	83	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	192	203
Liabilities:
Price risk management instruments, gross subject to netting	83	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	19	16
Fair Value Measured at Net Asset Value | Long-term disability trust
Assets:
Assets measured at NAV	$ 142	$ 155

DERIVATIVES (Outstanding Deriva

DERIVATIVES (Outstanding Derivative Balances) (Details) - Commodity Risk - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	$ 116	$ 90
Derivative Asset, Netting	0	0
Cash Collateral	51	98
Total Derivative Balance, Assets	167	188
Current assets – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	47	44
Derivative Asset, Netting	(4)	(1)
Cash Collateral	48	89
Total Derivative Balance, Assets	91	132
Other noncurrent assets – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Assets	161	165
Derivative Asset, Netting	0	0
Cash Collateral	0	0
Total Derivative Balance, Assets	161	165
Current liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Liabilities	(25)	(29)
Derivative Liability, Netting	4	1
Cash Collateral	3	7
Total Derivative Balance, Liabilities	(18)	(21)
Noncurrent liabilities – other
Derivatives And Hedging Activities [Line Items]
Gross Derivative Liabilities	(67)	(90)
Derivative Liability, Netting	0	0
Cash Collateral	0	2
Total Derivative Balance, Liabilities	$ (67)	$ (88)

FAIR VALUE MEASUREMENTS (Level

FAIR VALUE MEASUREMENTS (Level 3 Measurements and Sensitivity Analysis) (Details) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2019USD ($)$ / MWh	Dec. 31, 2018USD ($)$ / MWh
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	$ 7,477	$ 5,350
Liabilities	$ 85	$ 109
Congestion revenue rights | Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unobservable input (dollars per mwh) | $ / MWh	(13.11)	(18.61)
Congestion revenue rights | Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unobservable input (dollars per mwh) | $ / MWh	22.76	32.26
Power purchase agreements | Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unobservable input (dollars per mwh) | $ / MWh	19.68	19.81
Power purchase agreements | Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unobservable input (dollars per mwh) | $ / MWh	38.80	38.80
Market approach | Congestion revenue rights
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	$ 191	$ 203
Liabilities	64	75
Discounted cash flow | Power purchase agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	1	0
Liabilities	$ 19	$ 33

FAIR VALUE MEASUREMENTS (Leve_2

FAIR VALUE MEASUREMENTS (Level 3 Reconciliation) (Details) - Level 3 - Price Risk Management Instruments - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning asset (liability) balance	$ 129	$ 40	$ 95	$ 42
Net realized and unrealized gains: Included in regulatory assets and liabilities or balancing accounts	(20)	(6)	14	(8)
Ending asset (liability) balance	$ 109	$ 34	$ 109	$ 34

FAIR VALUE MEASUREMENTS (Carryi

FAIR VALUE MEASUREMENTS (Carrying Amount and Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions	Feb. 01, 2019	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Proceeds from debtor-in-possession credit facility	$ 350	$ 1,850	$ 0
Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument		0		$ 350
Utility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument		3,215		3,215
Proceeds from debtor-in-possession credit facility		1,850	$ 0
Utility | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument		1,500		14,747
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument		0		350
Carrying Amount | Utility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt financial instrument		$ 1,500		$ 17,450

FAIR VALUE MEASUREMENTS (Schedu

FAIR VALUE MEASUREMENTS (Schedule of Unrealized Gains (Losses) Related to Available-for-Sale Investments) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	$ 1,943	$ 1,885
Total Unrealized Gains	1,570	1,276
Total Unrealized Losses	(6)	(23)
Total Fair Value	3,507	3,138
Amount primarily related to deferred taxes on appreciation of investment value	491	408
Short-term investments
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	16	29
Total Unrealized Gains	0	0
Total Unrealized Losses	0	0
Total Fair Value	16	29
Global equity securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	496	568
Total Unrealized Gains	1,486	1,246
Total Unrealized Losses	(4)	(5)
Total Fair Value	1,978	1,809
Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost	1,431	1,288
Total Unrealized Gains	84	30
Total Unrealized Losses	(2)	(18)
Total Fair Value	$ 1,513	$ 1,300

FAIR VALUE MEASUREMENTS (Sche_2

FAIR VALUE MEASUREMENTS (Schedule of Maturities on Debt Securities) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Total maturities of fixed-income securities	$ 3,507	$ 3,138
Fixed-income securities
Debt Securities, Available-for-sale [Line Items]
Less than 1 year	26
1–5 years	541
5–10 years	340
More than 10 years	606
Total maturities of fixed-income securities	$ 1,513	$ 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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Fair Value Disclosures [Abstract]
Proceeds from sales and maturities of nuclear decommissioning trust investments	$ 171	$ 308	$ 517	$ 802
Gross realized gains on securities	56	11	22	48
Gross realized losses on securities	$ (26)	$ (5)	$ (7)	$ (9)

WILDFIRE-RELATED CONTINGENCIE_2

WILDFIRE-RELATED CONTINGENCIES (Summary of Estimated Liabilities) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Loss Contingencies [Line Items]
Wildfire-related claims reclassified to current liabilities	$ 100	$ 14,226
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Total wildfire-related claims	18,112	14,226
Wildfire-related claims reclassified from liabilities subject to compromise	100
Wildfire-related claims reclassified to current liabilities	100	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	5,500	3,500
Pacific Gas & Electric Co | 2018 Camp fire
Loss Contingencies [Line Items]
Total wildfire-related claims	$ 12,400	$ 10,500

WILDFIRE-RELATED CONTINGENCIE_3

WILDFIRE-RELATED CONTINGENCIES (Wildfire-Related Claims Narrative) (Details) - Pacific Gas & Electric Co - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
2018 Camp fire
Loss Contingencies [Line Items]
Legal and other costs	$ 19		$ 32
2017 Northern California wildfires
Loss Contingencies [Line Items]
Legal and other costs	$ 7	$ 46	$ 41	$ 68

WILDFIRE-RELATED CONTINGENCIE_4

WILDFIRE-RELATED CONTINGENCIES (2018 Camp Fire Background) (Details) - Pacific Gas & Electric Co - 2018 Camp fire	Jan. 04, 2019aresidencefatalitystructure
Loss Contingencies [Line Items]
Number of acres burned (acre) | a	153,336
Number of fatalities (fatality)	85
Number of residences destroyed (residence) | residence	13,972
Number of commercial structures destroyed (structure) | structure	528
Number of other buildings destroyed (building)	4,293

WILDFIRE-RELATED CONTINGENCIE_5

WILDFIRE-RELATED CONTINGENCIES (2017 Northern California Wildfires Background) (Details) - Pacific Gas & Electric Co a in Thousands	Jun. 30, 2019wildfirereport	Jun. 27, 2019wildfireviolation	Jan. 04, 2019wildfire	Jun. 30, 2018wildfire	Oct. 30, 2017awildfirefatalitystructure
2017 Northern California wildfires
Loss Contingencies [Line Items]
Number of wildfires (wildfire) | 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 investigation reports issued (report) | report	19
Number of supplementary investigation reports issued (report) | report	2
Number of fires in which determination has been reported on (wildfire) | wildfire	21			16
Number of alleged violations (violation) | violation		27
Alleged violations, number of wildfires (wildfire) | wildfire		12
Cherokee, La Porte and Tubbs Fires
Loss Contingencies [Line Items]
Number of alleged violations (violation) | violation		0
37 Fire
Loss Contingencies [Line Items]
Number of alleged violations (violation) | violation		0

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 (Plan Support Agreements with Public Entities) (Details) - Settled Litigation	Jun. 18, 2019USD ($)
Public Entity Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	$ 1,000,000,000
Fund to support defense or resolution of claims for each PSA	10,000,000
2017 Northern California Wildfire Public Entities Claims
Loss Contingencies [Line Items]
Settlement reached	415,000,000
Town Of Paradise Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	270,000,000
County Of Butte Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	252,000,000
Paradise Recreation & Park District Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	47,500,000
County Of Yuba Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	12,500,000
Calaveras County Water District Wildfire Claims
Loss Contingencies [Line Items]
Settlement reached	$ 3,000,000

WILDFIRE-RELATED CONTINGENCIE_8

WILDFIRE-RELATED CONTINGENCIES (Potential Losses in Connection with the 2018 Camp Fire and 2017 Northern California Wildfires) (Details) insurance_claim in Thousands, $ in Millions	May 08, 2019USD ($)	Sep. 06, 2018USD ($)insurance_claim	Jun. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2015USD ($)
November 2018 Fires
Loss Contingencies [Line Items]
Total insurance claims received by insurers	$ 12,000
2018 Camp fire
Loss Contingencies [Line Items]
Total insurance claims received by insurers	8,600
Loss in period			$ 1,900	$ 12,400	$ 10,500
2017 Northern California wildfires
Loss Contingencies [Line Items]
Total insurance claims received by insurers		$ 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	$ 18,600
Estimate of possible losses			$ 30,000	$ 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_9

WILDFIRE-RELATED CONTINGENCIES (2018 Camp Fire and 2017 Northern California Wildfires Accounting Charge) (Details) $ in Millions	Jul. 23, 2019USD ($)	Jun. 30, 2019USD ($)wildfire	Dec. 31, 2018USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2019USD ($)wildfire	Dec. 31, 2018USD ($)
2018 Camp fire
Loss Contingencies [Line Items]
Accrued losses		$ 1,900			$ 12,400	$ 10,500
2017 Northern California wildfires
Loss Contingencies [Line Items]
Number of fires with probable losses (wildfire) | wildfire		21			21
Loss from claims related to wildfire		$ 2,000	$ 1,000	$ 2,500	$ 5,500	$ 3,500
2017 Northern California Wildfires, other than Tubbs and 37 Fires
Loss Contingencies [Line Items]
Number of fires with probable losses (wildfire) | wildfire		19			19
Number of fires with probable losses, as previously determined (wildfire) | wildfire		17			17
2017 Northern California Wildfires, Youngs and Pressley Fires
Loss Contingencies [Line Items]
Number of fires with probable losses (wildfire) | wildfire		2			2
2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Loss from claims related to wildfire					$ 17,900
2018 Camp Fire and 2017 Northern California Wildfires, Clean-up and Fire Suppression Costs
Loss Contingencies [Line Items]
Loss from claims related to wildfire					900
Subrogated Insurance Claimholders | 2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Loss from claims related to wildfire					8,500
Individual Claimholders | 2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Loss from claims related to wildfire					7,500
Supporting Public Entities | 2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Loss from claims related to wildfire					$ 1,000
Subsequent Event | Subrogated Insurance Claimholders | 2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Insurance claims (in excess of)	$ 20,000
Plan of reorganization, settlement value of insurance claims	$ 15,800

WILDFIRE-RELATED CONTINGENCI_10

WILDFIRE-RELATED CONTINGENCIES (Loss Recoveries) (Details) - USD ($) $ in Millions	Jul. 08, 2019	Jun. 30, 2019	Sep. 30, 2018	Jul. 31, 2018
2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Liability insurance coverage			$ 1,400	$ 842
Initial self-insured retention per occurrence			10	10
Further retention per occurrence				$ 40
Liability insurance coverage, general liability			700
Liability insurance coverage, property damages			700
Liability insurance coverage, property damages, reinsurance			$ 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
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%

WILDFIRE-RELATED CONTINGENCI_11

WILDFIRE-RELATED CONTINGENCIES (Summary of Insurance Receivables) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Insurance Receivable [Roll Forward]
Reimbursements	$ 35	$ (144)
2018 Camp fire
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	1,380
Accrued insurance recoveries	0
Reimbursements	0
Insurance Receivable, Ending Balance	1,380
2017 Northern California wildfires
Insurance Receivable [Roll Forward]
Insurance Receivable, Beginning Balance	829
Accrued insurance recoveries	0
Reimbursements	0
Insurance Receivable, Ending Balance	$ 829

WILDFIRE-RELATED CONTINGENCI_12

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

WILDFIRE-RELATED CONTINGENCI_13

WILDFIRE-RELATED CONTINGENCIES (Wildfire-Related Securities Class Action Litigation) (Details) - Securities Class Actions Filed in United States District Court for the Northern District of California	Feb. 22, 2019offering	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_14

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

WILDFIRE-RELATED CONTINGENCI_15

WILDFIRE-RELATED CONTINGENCIES (Clean-up and Repair Costs) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Loss Contingencies [Line Items]
Capital expenditures	$ 836	$ 317
Total long-term regulatory assets	5,349		$ 4,964
Catastrophic event memorandum account
Loss Contingencies [Line Items]
Total long-term regulatory assets	918		790
Pacific Gas & Electric Co
Loss Contingencies [Line Items]
Capital expenditures	836	$ 317
Total long-term regulatory assets	5,349		$ 4,964
Pacific Gas & Electric Co | 2018 Camp fire
Loss Contingencies [Line Items]
Service restoration and repair costs	655
Capital expenditures	236
Pacific Gas & Electric Co | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Service restoration and repair costs	334
Capital expenditures	161
Pacific Gas & Electric Co | Catastrophic event memorandum account | 2018 Camp fire
Loss Contingencies [Line Items]
Total long-term regulatory assets	0
Pacific Gas & Electric Co | Catastrophic event memorandum account | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Total long-term regulatory assets	$ 88

WILDFIRE-RELATED CONTINGENCI_16

WILDFIRE-RELATED CONTINGENCIES (Wildfire Assistance Fund) (Details) - USD ($) $ in Millions	Aug. 02, 2019	Jun. 30, 2019	May 24, 2019	Dec. 31, 2018
Loss Contingencies [Line Items]
Wildfire-related claims		$ 100		$ 14,226
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		$ 100		$ 14,226
Subsequent Event | 2018 Camp Fire and 2017 Northern California Wildfires
Loss Contingencies [Line Items]
Wildfire-related claims	$ 105

WILDFIRE-RELATED CONTINGENCI_17

WILDFIRE-RELATED CONTINGENCIES (2015 Butte Fire) (Details) household in Thousands, $ in Millions

Jan. 28, 2019contractorhouseholdplaintiff

Sep. 06, 2018plaintiff

Mar. 02, 2018USD ($)

Mar. 01, 2018USD ($)

Apr. 13, 2017USD ($)

Jan. 29, 2019USD ($)

Nov. 30, 2018USD ($)

May 31, 2017USD ($)

Sep. 30, 2018plaintiff

Jun. 30, 2019USD ($)

Jun. 30, 2018USD ($)

Dec. 31, 2018USD ($)

May 01, 2018decision

May 23, 2016contractor

Apr. 28, 2016aoutbuildingfatalityhomecomercial_propertystructure

Loss Contingencies [Line Items]

Wildfire-related insurance receivable

$ 35

$ (144)

2015 Butte fire

Loss Contingencies [Line Items]

Loss contingency liability

212

$ 226

Payments for claims

$ (14)

Pacific Gas & Electric Co

Loss Contingencies [Line Items]

Wildfire-related insurance receivable

35

$ (144)

Pacific Gas & Electric Co | 2015 Butte fire

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

4

Number of plaintiffs, fire districts (plaintiff) | plaintiff

3

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

Loss contingency liability

212

226

Payments for claims

$ (14)

Settlement agreement paid

888

Settlement agreements entered

904

Insurance settlements receivable

50

$ 85

Wildfire-related insurance receivable

$ (35)

Agreement Reached in Litigation to Stipulate to Judgment on Inverse Condemnation Grounds | Pacific Gas & Electric Co | 2015 Butte fire

Loss Contingencies [Line Items]

Number of previous appellate courts decisions (decision) | decision

2

Number of plaintiffs in lawsuit (plaintiff) | plaintiff

2

County of Calaveras | Pacific Gas & Electric Co | 2015 Butte fire

Loss Contingencies [Line Items]

Value of claims brought against company

$ 167

$ 85

Settlement reached

$ 25.4

Settled Litigation | Pacific Gas & Electric Co | 2015 Butte fire

Loss Contingencies [Line Items]

Number of plaintiffs, fire districts (plaintiff) | plaintiff

3

OTHER CONTINGENCIES AND COMMI_3

OTHER CONTINGENCIES AND COMMITMENTS (Enforcement and Litigation Matters) (Details) - Pacific Gas & Electric Co $ in Millions	Apr. 16, 2019	Jan. 31, 2017USD ($)	May 14, 2019condition	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	5 years
Oversight by third-party monitor period, application for early termination, term		3 years
Damages awarded, value | $		$ 3
Number of additional probation conditions (condition) | condition			2

OTHER CONTINGENCIES AND COMMI_4

OTHER CONTINGENCIES AND COMMITMENTS (CPUC and FERC Matters) (Details) $ in Thousands	Jun. 30, 2019USD ($)	Jun. 27, 2019wildfireviolation	Sep. 21, 2018	May 17, 2018USD ($)	Apr. 26, 2018USD ($)	Jun. 28, 2019USD ($)	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 GT&S revenue requirement reduction					31,750
2019 GT&S 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
Settlement agreement, proposed penalty						$ 10,000
Settlement agreement, proposed payment to California General Fund						2,000
Settlement agreement, proposed forgone revenue collection, 2019 GT&S rate case						5,000
Settlement agreement, proposed forgone revenue collection, 2020 GRC cycle						1,000
Settlement agreement, proposed compensation payments						2,000
Settlement agreement, proposed compensation payments, San Bruno						1,000
Settlement agreement, proposed compensation payments, San Carlos						$ 1,000
Loss contingency liability	$ 4,000
Disallowance of Plant Costs
Loss Contingencies [Line Items]
Accrual for GTandS revenue requirement reduction	16,000
Pacific Gas & Electric Co | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Number of alleged violations (violation) | violation		27
Alleged violations, number of wildfires (wildfire) | wildfire		12
Qualifications of vegetation management personnel, corrective actions, period		30 days
Pacific Gas & Electric Co | Cherokee, La Porte and Tubbs Fires
Loss Contingencies [Line Items]
Number of alleged violations (violation) | violation		0
Pacific Gas & Electric Co | 37 Fire
Loss Contingencies [Line Items]
Number of alleged violations (violation) | violation		0
Pacific Gas & Electric Co | Ex Parte Communications
Loss Contingencies [Line Items]
Loss contingency liability	$ 4,000
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%
Minimum | Pacific Gas & Electric Co | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Prehearing conference, period after initiation of proceedings		45 days
Maximum | Pacific Gas & Electric Co | 2017 Northern California wildfires
Loss Contingencies [Line Items]
Prehearing conference, period after initiation of proceedings		60 days

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	Jun. 30, 2019	Dec. 31, 2018
Disclosure Commitments And Contingencies Environmental Remediation Liability Composed [Abstract]
Topock natural gas compressor station	$ 346	$ 369
Hinkley natural gas compressor station	142	146
Former manufactured gas plant sites owned by the Utility or third parties	580	520
Utility-owned generation facilities (other than fossil fuel-fired), other facilities, and third-party disposal sites	112	111
Fossil fuel-fired generation facilities and sites	125	137
Total environmental remediation liability	$ 1,305	$ 1,283

OTHER CONTINGENCIES AND COMMI_7

OTHER CONTINGENCIES AND COMMITMENTS (Environmental Remediation Contingencies Narrative) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Long-term Purchase Commitment [Line Items]
Amount of environmental loss accrual expected to be recovered	$ 960
Pacific Gas & Electric Co
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	18,112	$ 14,226
Topock Site
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 302
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	$ 139
Former Manufactured Gas Plant
Long-term Purchase Commitment [Line Items]
Utility undiscounted future costs	$ 528
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	$ 98
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	$ 86

OTHER CONTINGENCIES AND COMMI_8

OTHER CONTINGENCIES AND COMMITMENTS (Wildfire Insurance) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jul. 01, 2019	Dec. 31, 2018
Loss Contingencies [Line Items]
Costs for insurance coverage	$ 190
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
Subsequent Event | Insurance Coverage for Wildfire Events
Loss Contingencies [Line Items]
Liability insurance coverage		$ 430
Subsequent Event | Insurance Coverage for Wildfire Liabilities
Loss Contingencies [Line Items]
Liability insurance coverage		520
Catastrophic bond reinsurance instrument		$ 10

OTHER CONTINGENCIES AND COMMI_9

OTHER CONTINGENCIES AND COMMITMENTS (Nuclear Insurance) (Details) $ in Millions	6 Months Ended
	Jun. 30, 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	$ 41
European Mutual Association for Nuclear Insurance
Long-term Purchase Commitment [Line Items]
Amount of property damage coverage provided by NEIL	$ 5

OTHER CONTINGENCIES AND COMM_10

OTHER CONTINGENCIES AND COMMITMENTS (Tax Matters) (Details) $ in Millions	6 Months Ended
	Jun. 30, 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

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - Unfavorable Regulatory Action - Pacific Gas & Electric Co - Subsequent Event $ in Millions	Jul. 12, 2019USD ($)
Subsequent Event [Line Items]
Disallowance cap, transmission and distribution equity rate base	$ 2,300
Expected wildfire fund allocation metric, percentage	64.20%
Expected wildfire fund allocation metric, initial contribution	$ 4,800
Expected wildfire fund allocation metric, annual contributions	$ 193