8-K/A

_____________________________________________________________________________________

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

_____________________________________________________________________________________

FORM 8-K/A

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Date of Report: November 4, 2016

(Date of earliest event reported)

Commission File Number	Exact Name of Registrant as specified in its charter	State or Other Jurisdiction of Incorporation or Organization	IRS Employer Identification Number
1-12609	PG&E CORPORATION	California	94-3234914
1-2348	PACIFIC GAS AND ELECTRIC COMPANY	California	94-0742640

77 Beale Street P.O. Box 770000 San Francisco, California 94177  (Address of principal executive offices) (Zip Code) (415) 973-1000 (Registrant's telephone number, including area code)	77 Beale Street P.O. Box 770000 San Francisco, California 94177 (Address of principal executive offices) (Zip Code) (415) 973-7000 (Registrant's telephone number, including area code)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):

☐	Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
☐	Soliciting Material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
☐	Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b)
☐	Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Item 2.02 Results of Operations and Financial Condition

On November 4, 2016, PG&E Corporation filed with the Securities and Exchange Commission ("SEC") a Current Report on Form 8-K (the "Original Form 8-K") in connection with its financial results and the financial results of its subsidiary, Pacific Gas and Electric Company ("Utility") for the quarter ended September 30, 2016.  PG&E Corporation furnished to the SEC its earnings announcement, as Exhibit 99.1 to the Original Form 8-K, a "Third Quarter Earnings Call" slide presentation, as Exhibit 99.2 and a "Business Update" slide presentation, as Exhibit 99.3.

PG&E Corporation is amending the Original Form 8-K to correct slide 10 of the "Business Update" slide presentation (the "Revised Presentation").  The Revised Presentation is attached as Exhibit 99.3 to this report.  Also attached to this report are previously furnished with the Original Form 8-K, Exhibits 99.1 and 99.2, unchanged.

The information included in this Current Report on Form 8-K is being furnished, and shall not be deemed to be "filed" for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), or otherwise subject to the liabilities of that section.

Item 7.01 Regulation FD Disclosure

During the 51^st EEI Financial Conference on November 6-8, 2016, in Phoenix, Arizona, management of PG&E Corporation and the Utility will use the Revised Presentation, attached as Exhibit 99.3 to this report, along with the "Third Quarter Earnings Call" slide presentation that was previously furnished as Exhibit 99.2 attached to the Original Form 8-K, and is also attached as Exhibit 99.2 to this report.

The information included in Exhibits 99.1, 99.2 and 99.3 to this report is incorporated by reference in response to this Item 7.01 and, with the information included in this Item 7.01, is being furnished, and shall not be deemed to be "filed" for purposes of Section 18 of the Exchange Act, or otherwise subject to liabilities of that section.

Item 9.01 Financial Statements and Exhibits

Exhibits

The following Exhibits are being furnished, and are not deemed to be filed:

Exhibit 99.1	PG&E Corporation earnings announcement dated November 4, 2016
Exhibit 99.2	Slide presentation "Third Quarter Earnings Call" dated November 4, 2016
Exhibit 99.3	Slide presentation "Business Update" dated November 4, 2016

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	SIGNATURES
	Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.
		PG&E CORPORATION
		By:	DAVID S. THOMASON
Dated:November 4, 2016			David S. Thomason Vice President and Controller
		PACIFIC GAS AND ELECTRIC COMPANY
		By:	DAVID S. THOMASON
Dated:November 4, 2016			David S. Thomason Vice President, Chief Financial Officer and Controller

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Exhibit Index

The following Exhibits are being furnished, and are not deemed to be filed:

Exhibit 99.1	PG&E Corporation earnings announcement dated November 4, 2016
Exhibit 99.2	Slide presentation "Third Quarter Earnings Call" dated November 4, 2016
Exhibit 99.3	Slide presentation "Business Update" dated November 4, 2016

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EX-99.01

EXHIBIT 99.1

Corporate Relations  |  77 Beale Street  |  San Francisco, CA  94105  |  1 (415) 973-5930    | www.pgecorp.com
	November 4, 2016

PG&E Corporation Reports Third-Quarter 2016 Financial Results

▪ Net income was $0.77 per share on a GAAP basis, up from $0.63 per share in Q3 last year

▪ Non-GAAP earnings from operations were $0.94 per share, up from $0.84 per share in Q3 last year

▪ PG&E is adjusting previously issued guidance range for projected 2016 GAAP earnings to $2.79 to $3.05 per share and maintaining previously issued guidance of $3.65 to $3.85 per share for projected non-GAAP earnings from operations

▪ Guidance for 2017 is being initiated at $3.51 to $3.80 per share for projected GAAP earnings and $3.55 to $3.75 per share for projected non-GAAP earnings from operations

San Francisco, Calif. — PG&E Corporation's (NYSE: PCG) third-quarter 2016 net income after dividends on preferred stock (also called "income available for common shareholders") was $388 million, or $0.77 per share, as reported in accordance with generally accepted accounting principles (GAAP). GAAP earnings for the same period in 2015 were $307 million, or $0.63 per share.

GAAP results include items that management does not consider part of normal, ongoing operations (items impacting comparability), totaling $137 million pre-tax, or $0.17 per share, in the third quarter of 2016. This includes $59 million pre-tax for safety-related expenditures disallowed as part of the San Bruno penalty, $31 million pre-tax for work to clear pipeline rights-of-way, $23 million pre-tax for legal and regulatory costs related to natural gas matters and regulatory communications, $16 million pre-tax for expenses related to the Butte fire, $4 million pre-tax for fines associated with the federal criminal trial and the California Public Utilities Commission's (CPUC) gas distribution record-keeping investigation, and $4 million pre-tax for disallowances imposed by the CPUC in connection with prohibited ex-parte communications.

"Results for the third quarter reflect PG&E's solid operating performance and strong capital investment program. Looking ahead, we continue to see significant growth and investment opportunities in support of our commitment to deliver safe, reliable, affordable and clean energy for customers," said PG&E Corporation Chairman and CEO Tony Earley.

Among the company's operational highlights from the third quarter, PG&E:

▪ Became the nation's first energy provider to earn the American Chemistry Council's RC14001® management system standard for process safety.

▪ Replaced more than 100 poles and over 10 miles of conductor to restore power to customers impacted by the Clayton wildfire, which destroyed hundreds of structures in Lake County.

▪ Completed PG&E's largest liquefied natural gas/compressed natural gas project to date in support of pipeline safety upgrades and strength testing in California's North Valley.

▪ Announced the launch of new technology demonstration projects with General Electric, Solar City and others to advance integration of distributed energy resources, such as solar and battery storage.

▪ Inspected its one millionth gas line using the highly advanced Picarro methane detection technology.

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Earnings from Operations

On a non-GAAP basis, excluding items impacting comparability, PG&E Corporation's earnings from operations for the third quarter of 2016 were $471 million, or $0.94 per share, compared with $412 million, or $0.84 per share, during the same period in 2015. The difference in quarter-over-quarter earnings from operations reflected additional authorized revenue collected through rates as a result of the final phase one decision in Pacific Gas and Electric Company's 2015 Gas Transmission and Storage (GT&S) rate case and higher rate base earnings. These increases were partially offset by certain timing-related tax expenses.

Earnings Guidance

PG&E Corporation is adjusting its previously issued guidance for projected 2016 GAAP earnings to the range of $2.79 to $3.05 per share and is maintaining previously issued guidance for projected non-GAAP earnings from operations in the range of $3.65 to $3.85 per share.

PG&E Corporation is providing 2017 guidance for projected GAAP earnings in the range of $3.51 to $3.80 per share, which includes forecasts for the revenue true-up authorized in the 2015 GT&S rate case, pipeline-related costs, legal and regulatory expenses, penalties imposed by the CPUC, as well as other items. On a non-GAAP basis, the guidance range for projected 2017 earnings from operations is $3.55 to $3.75 per share.

Guidance is based on various assumptions and forecasts, including those relating to authorized revenues, future expenses, capital expenditures, rate base, equity issuances, and certain other factors. PG&E Corporation discloses historical financial results and provides guidance based on "earnings from operations" in order to provide a measure that allows investors to compare the underlying financial performance of the business from one period to another, exclusive of items impacting comparability. See the accompanying tables for a reconciliation of earnings from operations to consolidated income available for common shareholders for the third quarter of 2016 and for 2016 and 2017 earnings guidance.

Supplemental Financial Information

In addition to the financial information accompanying this release, presentation slides for today's conference call with the financial community have been furnished to the Securities and Exchange Commission and are available on PG&E Corporation's website at: http://investor.pgecorp.com/financials/quarterly-earnings-reports/default.aspx.

Conference Call with the Financial Community to Discuss Financial Results

Today's call at 11:00 a.m., Eastern Time, is open to the public on a listen-only basis via webcast. Please visit http://investor.pgecorp.com/news-events/events-and-presentations/default.aspx for more information and instructions for accessing the webcast. The webcast call and the related materials will be available for replay through the website for at least one year. Alternatively, a toll-free replay of the conference call may be accessed shortly after the live call through November 18, 2016, by dialing (866) 415-9493. International callers may dial (205) 289-3247. For both domestic and international callers, the confirmation code 1659# will be required to access the replay.

About PG&E Corporation

PG&E Corporation (NYSE: PCG) is a Fortune 200 energy-based holding company, headquartered in San Francisco. It is the parent company of Pacific Gas and Electric Company, an energy company that serves 16 million Californians across a 70,000 square-mile service area in Northern and Central California. For more information, visit http://www.pgecorp.com.

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Forward-Looking Statements

Management's statements providing guidance for PG&E Corporation's 2016 and 2017 financial results and the assumptions and forecasts underlying such guidance constitute forward-looking statements that reflect management's judgments and opinions.  These statements and assumptions are necessarily subject to various risks and uncertainties, the realization or resolution of which may be outside management's control.  Actual results may differ materially.  Factors that could cause actual results to differ materially include, but are not limited to:

· the timing and outcomes of the final phase two CPUC decision in the 2015 GT&S rate case, the 2017 GRC, the TO rate cases, and other ratemaking and regulatory proceedings;

· the timing and outcomes of the debarment proceeding and potential remedial and other measures that may be imposed on the Utility as a result of the debarment proceeding and the jury's verdict in the federal criminal trial of the Utility (including a potential appointment of one or more independent third-party monitor(s)), the Utility's motion for judgment of acquittal, the SED's unresolved enforcement matters relating to the Utility's compliance with natural gas-related laws and regulations, and other investigations that have been or may be commenced relating to the Utility's compliance with natural gas-related laws and regulations;

· the timing and outcomes of (i) the CPUC's investigation of communications between the Utility and the CPUC that may have violated the CPUC's rules regarding ex parte communications or are otherwise alleged to be improper, and (ii) the U.S. Attorney's Office in San Francisco and the California Attorney General's office investigations in connection with communications between the Utility's personnel and CPUC officials, and whether such matters negatively affect the final decisions to be issued in phase two of the 2015 GT&S rate case and other ratemaking proceedings;

· the timing and outcomes of the Butte fire litigation, whether the Utility's insurance is sufficient to cover the Utility's liability resulting therefrom and otherwise available, and whether additional investigations and proceedings in connection with Butte fire will be opened;

· the Utility's ability to control its costs within the authorized levels of spending and the extent to which the Utility incurs unrecoverable costs that are higher than the forecasts of such costs;

· changes in cost forecasts or the scope and timing of planned work resulting from changes in customer demand for electricity and natural gas or other reasons;

· the outcomes of the SED's investigations of potential violations identified though audits, investigations, or self-reports;

· the impact that reductions in customer demand for electricity and natural gas have on the Utility's ability to make and recover its investments through rates and earn its authorized return on equity, and whether the Utility is successful in addressing the impact of growing distributed and renewable generation resources and changing customer demand for natural gas and electric services;

· the amount and timing of charges reflecting probable liabilities for third-party claims, the extent to which costs incurred in connection with third-party claims or litigation can be recovered through insurance, rates, or from other third parties, and whether the Utility can continue to obtain insurance and whether insurance coverage is adequate for future losses or claims, especially following a major event that causes widespread third-party losses;

· the ability of PG&E Corporation and the Utility to access capital markets and other sources of debt and equity financing in a timely manner on acceptable terms, and the amount and timing of additional common stock and debt issuances by PG&E Corporation;

· changes in estimated environmental remediation costs, including costs associated with the Utility's natural gas compressor sites;

· the outcome of federal or state tax audits and the impact of any changes in federal or state tax laws, policies, regulations, or their interpretation;

· the impact of changes in GAAP, standards, rules, or policies, including those related to regulatory accounting, and the impact of changes in their interpretation or application; and

· the other factors disclosed in PG&E Corporation and the Utility's joint Annual Report on Form 10-K for the year ended December 31, 2015 and Quarterly Reports on Form 10-Q for the quarters ended March 31, June 30, and September 30, 2016.

###

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PG&E Corporation

Consolidated Statements of Income

(in millions, except per share amounts)

	(Unaudited)
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
(in millions, except per share amounts)	2016			2015			2016			2015
Operating Revenues
Electric	$	3,994		$	3,868		$	10,590		$	10,344
Natural gas		816			682			2,363			2,322
Total operating revenues		4,810			4,550			12,953			12,666
Operating Expenses
Cost of electricity		1,613			1,681			3,719			3,958
Cost of natural gas		80			50			377			442
Operating and maintenance		1,783			1,621			5,631			5,028
Depreciation, amortization, and decommissioning		694			653			2,090			1,935
Total operating expenses		4,170			4,005			11,817			11,363
Operating Income		640			545			1,136			1,303
Interest income		8			2			17			6
Interest expense		(211	)		(194	)		(621	)		(575	)
Other income, net		24			24			74			100
Income Before Income Taxes		461			377			606			834
Income tax provision (benefit)		70			67			(105	)		84
Net Income		391			310			711			750
Preferred stock dividend requirement of subsidiary		3			3			10			10
Income Available for Common Shareholders	$	388		$	307		$	701		$	740
Weighted Average Common Shares Outstanding, Basic		501			486			497			481
Weighted Average Common Shares Outstanding, Diluted		503			489			500			484
Net Earnings Per Common Share, Basic	$	0.77		$	0.63		$	1.41		$	1.54
Net Earnings Per Common Share, Diluted	$	0.77		$	0.63		$	1.40		$	1.53
Dividends Declared Per Common Share	$	0.49		$	0.46		$	1.44		$	1.37

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Reconciliation of PG&E Corporation's Earnings from Operations to Consolidated Income Available for Common Shareholders in Accordance with Generally Accepted Accounting Principles ("GAAP")

Third Quarter and Year to Date ("YTD"), 2016 vs. 2015

(in millions, except per share amounts)

	Three Months Ended September 30,												Nine Months Ended September 30,
	Earnings						Earnings per Common Share (Diluted)						Earnings						Earnings per Common Share (Diluted)
	2016			2015			2016			2015			2016			2015			2016			2015
PG&E Corporation's
Earnings from Operations (1)	$	471		$	412		$	0.94		$	0.84		$	1,209		$	1,272		$	2.42		$	2.63
Items Impacting
Comparability: (2)
Pipeline related expenses (3)		(18	)		(19	)		(0.04	)		(0.04	)		(47	)		(38	)		(0.10	)		(0.08	)
Legal and regulatory
related expenses (4)		(14	)		(8	)		(0.03	)		(0.02	)		(32	)		(26	)		(0.06	)		(0.05	)
Fines and penalties (5)		(42	)		(84	)		(0.08	)		(0.16	)		(206	)		(497	)		(0.41	)		(1.03	)
Butte fire related costs,
net of insurance (6)		(9	)		-			(0.02	)		-			(110	)		-			(0.22	)		-
GT&S capital disallowance (7)		-			-			-			-			(113	)		-			(0.23	)		-
GT&S revenue timing impact (8)		-			-			-			-			-			-			-			-
Insurance recoveries (9)		-			6			-			0.01			-			29			-			0.06
PG&E Corporation's
Earnings on a GAAP basis	$	388		$	307		$	0.77		$	0.63		$	701		$	740		$	1.40		$	1.53

All amounts presented in the table above are tax adjusted at PG&E Corporation's tax rate of 40.75 percent except for fines, which are not tax deductible. See Footnote 5 below.

⁽¹⁾ "Earnings from operations" is a non-GAAP financial measure. See exhibit titled Use of Non-GAAP Financial Measures.

⁽²⁾ "Items impacting comparability" represent items that management does not consider part of the normal course of operations and affect comparability of financial results between periods. See exhibit titled Use of Non-GAAP Financial Measures.

⁽³⁾ The Utility incurred costs of $31 million (before the tax impact of $13 million) and $80 million (before the tax impact of $33 million), during the three and nine months ended September 30, 2016, respectively, for pipeline related expenses incurred in connection with the multi-year effort to identify and remove encroachments from transmission pipeline rights of way.

⁽⁴⁾ The Utility incurred costs of $23 million (before the tax impact of $9 million) and $54 million (before the tax impact of $22 million), during the three and nine months ended September 30, 2016, respectively, for legal and regulatory related expenses incurred in connection with various enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory communications.

⁽⁵⁾ The Utility incurred costs of $67 million (before the tax impact of $25 million) and $327 million (before the tax impact of $121 million), during the three and nine months ended September 30, 2016, respectively, associated with fines and penalties. This includes costs of $59 million (before the tax impact of $23 million) and $294 million (before the tax impact of $119 million), during the three and nine months ended September 30, 2016, respectively, associated with estimated safety-related cost disallowances imposed by the CPUC in its April 9, 2015 decision ("San Bruno Penalty Decision") in the gas transmission pipeline investigations. Specific projects to be disallowed will be determined in the CPUC's phase two decision of the 2015 Gas Transmission and Storage ("GT&S") rate case. The Utility also recorded $4 million (before the tax impact of $2 million), during the three and nine months ended September 30, 2016, for probable disallowances that will be imposed by the CPUC in its phase two decision of the 2015 GT&S rate case for prohibited ex parte communications. In addition, the Utility accrued fines of $1 million and $26 million, during the three and nine months ended September 30, 2016, respectively, in connection with the modified presiding officer's decision approved by the CPUC on August 16, 2016 in its investigation regarding natural gas distribution record-keeping practices and $3 million, during the three and nine months ended September 30, 2016, in connection with the maximum statutory fine that may be imposed as a result of the jury verdict returned on August 9, 2016 in the federal criminal trial against the Utility. These fines are not tax deductible.

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	Three Months Ended			Nine Months Ended
(in millions, pre-tax)	September 30, 2016			September 30, 2016
Charge for disallowed capital	$	(51	)	$	(286	)
Charge for disallowed expense		(8	)		(8	)
GT&S ex parte disallowance		(4	)		(4	)
Gas distribution record-keeping fine		(1	)		(26	)
Federal criminal trial fine		(3	)		(3	)
Fines and penalties	$	(67	)	$	(327	)

Future fines or penalties may be imposed in connection with other enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory communications.

⁽⁶⁾ The Utility incurred costs of $16 million (before the tax impact of $7 million) and $186 million (before the tax impact of $76 million), during the three and nine months ended September 30, 2016, respectively, associated with the Butte fire, net of insurance. This includes accrued charges of $350 million (before the tax impact of $143 million), during the nine months ended September 30, 2016, related to estimated third-party claims in connection with the Butte fire, partially offset by $260 million (before the tax impact of $106 million) recorded during the nine months ended September 30, 2016, as probable of insurance recovery. No additional charges or insurance recoveries related to estimated third-party claims were recognized in the three months ended September 30, 2016. The Utility also incurred charges of $16 million (before the tax impact of $7 million) and $96 million (before the tax impact of $39 million), during the three and nine months ended September 30, 2016, respectively, for Utility clean-up, repair, and legal costs associated with the Butte fire.

	Three Months Ended			Nine Months Ended
(in millions, pre-tax)	September 30, 2016			September 30, 2016
Third-party claims and Utility clean-up, repair,
and legal costs	$	(16	)	$	(446	)
Insurance		-			260
Butte fire related costs, net of insurance	$	(16	)	$	(186	)

 ⁽⁷⁾ The Utility incurred charges of $190 million (before the tax impact of $77 million), during the nine months ended September 30, 2016, for capital expenditures that the Utility believes are probable of disallowance based on the CPUC phase one decision dated June 23, 2016 in the 2015 GT&S rate case, including $134 million (before the tax impact of $54 million) for a portion of the 2011 through 2014 capital expenditures in excess of adopted amounts and $56 million (before the tax impact of $23 million) for the Utility's estimate of 2015 through 2018 capital expenditures that are probable of exceeding authorized amounts. No additional charges were recognized in the three months ended September 30, 2016.

⁽⁸⁾ "GT&S revenue timing impact" refers to the revenues that are expected to be recorded in excess of the 2016 authorized revenue requirements after the CPUC issues a final phase two decision in the 2015 GT&S rate case to address the allocation of the $850 million disallowance for safety-related work adopted in the San Bruno Penalty Decision. Due to the uncertainty regarding the revenue requirement the CPUC will ultimately adopt, the Utility will not be able to record a true-up of revenues under-collected since January 1, 2015 until after a final phase two decision is issued.

⁽⁹⁾ Represents insurance recoveries of $10 million (before the tax impact of $4 million) and $49 million (before the tax impact of $20 million) for third-party claims and associated legal costs that the Utility received in connection with the San Bruno accident during the three and nine months ended September 30, 2015, respectively. No further insurance recoveries related to the San Bruno accident are expected.

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Key Drivers of PG&E Corporation's Earnings per Common Share ("EPS") from Operations

Third Quarter and YTD, 2016 vs. 2015

($/Share, Diluted)

Third Quarter 2015 EPS from Operations (1)	$	0.84
Timing of 2015 GT&S revenue (2)		0.11
Growth in rate base earnings		0.05
Regulatory and legal matters		0.05
Timing of taxes		(0.04	)
Increase in shares outstanding		(0.03	)
Miscellaneous		(0.04	)
Third Quarter 2016 EPS from Operations (1)	$	0.94
2015 YTD EPS from Operations  (1)	$	2.63
Growth in rate base earnings		0.15
Timing of 2015 GT&S revenue (2)		0.11
Timing of taxes		(0.20	)
Increase in shares outstanding		(0.08	)
Nuclear refueling outage		(0.06	)
Gain on disposition of SolarCity stock (3)		(0.03	)
Miscellaneous		(0.10	)
2016 YTD EPS from Operations  (1)	$	2.42

⁽¹⁾ See exhibit for a reconciliation of EPS from Operations to EPS on a GAAP basis. All amounts presented in the table above are tax adjusted at PG&E Corporation's tax rate of 40.75 percent.

⁽²⁾ Represents the incremental authorized revenue collected through rates beginning August 1, 2016 in accordance with the final phase one decision in the Utility's 2015 GT&S rate case during the three and nine months ended September 30, 2016.

⁽³⁾                   Represents the gain recognized during the three months ended March 31, 2015. No comparable gain was recognized for the same period in 2016.

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PG&E Corporation's 2016 Earnings per Share ("EPS") Guidance

2016 EPS Guidance	Low			High
Estimated EPS on an Earnings from Operations Basis (1)	$	3.65		$	3.85
Estimated Items Impacting Comparability: (2)
Pipeline related expenses (3)		(0.18	)		(0.12	)
Legal and regulatory related expenses (4)	~	(0.09	)	~	(0.09	)
Fines and penalties (5)	~	(0.56	)	~	(0.56	)
Butte fire related costs, net of insurance (6)	~	(0.22	)	~	(0.22	)
GT&S capital disallowance (7)		(0.23	)		(0.23	)
GT&S revenue timing impact (8)	~	0.42		~	0.42
Estimated EPS on a GAAP Basis	$	2.79		$	3.05

All amounts presented in the table above are tax adjusted at PG&E Corporation's tax rate of 40.75 percent except for fines, which are not tax deductible.  See Footnote 5 below.

⁽¹⁾ "Earnings from operations" is a non-GAAP financial measure. See exhibit titled Use of Non-GAAP Financial Measures.

⁽²⁾ "Items impacting comparability" represent items that management does not consider part of the normal course of operations and affect comparability of financial results between periods. See exhibit titled Use of Non-GAAP Financial Measures.

⁽³⁾ "Pipeline related expenses" includes costs incurred to identify and remove encroachments from transmission pipeline rights-of-way. The pre-tax range of estimated costs is shown below. The offsetting tax impacts for the low and high EPS guidance range are $61 million and $41 million, respectively.

	2016
	Low EPS				High EPS
(in millions, pre-tax)	guidance				guidance
Pipeline related expenses		$	(150	)		$	(100	)

⁽⁴⁾ "Legal and regulatory related expenses" includes costs incurred in connection with various enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory communications. The pre-tax range of estimated costs is shown below. The offsetting tax impact for the low and high EPS guidance range is $31 million.

	2016
	Low EPS				High EPS
(in millions, pre-tax)	guidance				guidance
Legal and regulatory related expenses	~	$	(75	)	~	$	(75	)

⁽⁵⁾ "Fines and penalties" includes actual and estimated future fines and penalties resulting from various enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory   communications. Guidance of $449 million is consistent with the estimated 2016 components of the $1.6 billion San Bruno Penalty Decision in the gas transmission pipeline investigations. Guidance reflects amounts recorded during the nine months ended September 30, 2016 related to probable disallowances that will be imposed by the CPUC in its phase two decision of the 2015 GT&S rate case for prohibited ex parte communications. Guidance is also consistent with the non-tax-deductible $26 million fine accrued in connection with the CPUC decision in its investigation regarding natural gas distribution record-keeping practices and the non-tax-deductible $3 million fine accrued in connection with the maximum statutory fine that may be imposed as a result of the jury verdict returned on August 9, 2016 in the federal criminal trial against the Utility. Guidance does not include amounts for other potential future fines or penalties. The pre-tax range of estimated costs is shown below. The offsetting tax impact for the low and high EPS guidance range is $171 million.

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	2016
	Low EPS			High EPS
(in millions, pre-tax)	guidance			guidance
Charge for disallowed capital	$	(286	)	$	(286	)
Charge for disallowed expense	~	(130	)	~	(130	)
GT&S ex parte disallowance		(4	)		(4	)
Gas distribution record-keeping fine		(26	)		(26	)
Federal criminal trial fine		(3	)		(3	)
Fines and penalties	~$	(449	)	~$	(449	)

⁽⁶⁾ "Butte fire related costs, net of insurance" includes charges of $446 million (before the tax impact of $182 million) recorded for the nine months ended September 30, 2016 related to estimated third-party claims and Utility clean-up, repair, and legal costs associated with the Butte fire. Guidance is consistent with $350 million corresponding to the low end of the estimated range of costs related to third-party claims. The Utility currently is unable to estimate the high end of the range. This amount is partially offset by $260 million (before the tax impact of $106 million) accrued as probable of insurance recovery for the nine months ended September 30, 2016. The pre-tax range of estimated costs is shown below. The offsetting tax impact for the low and high EPS guidance range is $76 million.

	2016
	Low EPS				High EPS
(in millions, pre-tax)	guidance				guidance
Third-party claims and Utility clean-up, repair, and legal costs		$	(446	)		$	(446	)
Insurance	~		260		~		260
Butte fire related costs, net of insurance	~	$	(186	)	~	$	(186	)

⁽⁷⁾ "GT&S capital disallowance" includes capital expenditures that the Utility believes are probable of disallowance based on the CPUC phase one decision dated June 23, 2016 in the 2015 GT&S rate case, including $134 million (before the tax impact of $54 million) for a portion of the 2011 through 2014 capital expenditures in excess of adopted amounts and $56 million (before the tax impact of $23 million) for the Utility's estimate of 2015 through 2018 capital expenditures that are probable of exceeding authorized amounts. The pre-tax range of estimated costs is shown below. The offsetting tax impact for the low and high EPS guidance range is $77 million.

	2016
	Low EPS				High EPS
(in millions, pre-tax)	guidance				guidance
GT&S capital disallowance		$	(190	)		$	(190	)

⁽⁸⁾ "GT&S revenue timing impact" refers to the revenues that are expected to be recorded in excess of the 2016 authorized revenue requirements after the CPUC issues a final phase two decision in the 2015 GT&S rate case to address the allocation of the $850 million disallowance for safety-related work adopted in the San Bruno Penalty Decision. Due to the uncertainty regarding the revenue requirement the CPUC will ultimately adopt in the final phase two decision, the Utility will not be able to record a true-up of revenues under-collected since January 1, 2015 until after the final phase two decision is issued. In addition, accounting rules allow the Utility to recognize revenues in a given year only if they will be collected from customers within 24 months of the end of that year. Because the phase one decision directs the Utility to collect the difference between the adopted "interim" revenue requirements and the amounts previously collected in rates, retroactive to January 1, 2015, over a 36-month period, the Utility will complete recording the full true-up of under-collected revenues in 2017. The pre-tax range of estimated revenues is shown below. The offsetting tax impact for the low and high EPS guidance range is $143 million.

	2016
	Low EPS			High EPS
(in millions, pre-tax)	guidance			guidance
GT&S revenue timing impact	~	$	350	~	$	350

Actual financial results for 2016 may differ materially from the guidance provided.  For a discussion of the factors that may affect future results, see the Forward-Looking Statements.

9

PG&E Corporation's 2017 Earnings per Share ("EPS") Guidance

2017 EPS Guidance	Low			High
Estimated EPS on an Earnings from Operations Basis (1)	$	3.55		$	3.75
Estimated Items Impacting Comparability: (2)
Pipeline related expenses (3)		(0.14	)		(0.09	)
Legal and regulatory related expenses (4)		(0.05	)		(0.01	)
Fines and penalties (5)	~	(0.03	)	~	(0.03	)
Butte fire related costs, net of insurance (6)		-			-
GT&S revenue timing impact (7)	~	0.18		~	0.18
Estimated EPS on a GAAP Basis	$	3.51		$	3.80

All amounts presented in the table above are tax adjusted at PG&E Corporation's tax rate of 40.75 percent except for fines, which are not tax deductible.

⁽¹⁾ "Earnings from operations" is a non-GAAP financial measure. See exhibit titled Use of Non-GAAP Financial Measures.

⁽²⁾ "Items impacting comparability" represent items that management does not consider part of the normal course of operations and affect comparability of financial results between periods. See exhibit titled Use of Non-GAAP Financial Measures.

⁽³⁾ "Pipeline related expenses" includes costs incurred to identify and remove encroachments from transmission pipeline rights-of-way. The pre-tax range of estimated costs is shown below. The offsetting tax impacts for the low and high EPS guidance range are $51 million and $33 million, respectively.

	2017
	Low EPS				High EPS
(in millions, pre-tax)	guidance				guidance
Pipeline related expenses		$	(125	)		$	(80	)

⁽⁴⁾ "Legal and regulatory related expenses" includes costs incurred in connection with various enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory communications. The pre-tax range of estimated costs is shown below. The offsetting tax impacts for the low and high EPS guidance range are $16 million and $4 million, respectively.

	2017
	Low EPS				High EPS
(in millions, pre-tax)	guidance				guidance
Legal and regulatory related expenses		$	(40	)		$	(10	)

⁽⁵⁾ "Fines and penalties" includes estimated future fines and penalties resulting from various enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory communications. Guidance is consistent with the estimated 2017 components of the $1.6 billion San Bruno Penalty Decision in the gas transmission pipeline investigations. Guidance does not include amounts for other potential future fines and penalties, including probable disallowances that will be imposed by the CPUC in its phase two decision of the 2015 GT&S rate case for prohibited ex parte communications. The pre-tax range of estimated costs is shown below. The offsetting tax impact for the low and high EPS guidance range is $12 million.

	2017
	Low EPS				High EPS
(in millions, pre-tax)	guidance				guidance
Charge for disallowed expense	~	$	(30	)	~	$	(30	)
GT&S ex parte disallowance			-				-
Fines and penalties	~	$	(30	)	~	$	(30	)

10

⁽⁶⁾ "Butte fire related costs, net of insurance" refers to estimated third-party claims and legal costs associated with the Butte fire, and any related insurance recovery. The Utility currently is unable to estimate the low and high end of the range for 2017.

	2017
	Low EPS			High EPS
(in millions, pre-tax)	guidance			guidance
Butte fire related costs, net of insurance		$	-		$	-

⁽⁷⁾ "GT&S revenue timing impact" refers to the revenues that are expected to be recorded in excess of the 2017 authorized revenue requirements after the CPUC issues a final phase two decision in the 2015 GT&S rate case to address the allocation of the $850 million disallowance for safety-related work adopted in the San Bruno Penalty Decision. Due to the uncertainty regarding the revenue requirement the CPUC will ultimately adopt in the final phase two decision, the Utility will not be able to record a true-up of revenues under-collected since January 1, 2015 until after the final phase two decision is issued. In addition, accounting rules allow the Utility to recognize revenues in a given year only if they will be collected from customers within 24 months of the end of that year. Because the phase one decision directs the Utility to collect the difference between the adopted "interim" revenue requirements and the amounts previously collected in rates, retroactive to January 1, 2015, over a 36-month period, the Utility will complete recording the full true-up of under-collected revenues in 2017. The pre-tax range of estimated revenues is shown below. The offsetting tax impact for the low and high EPS guidance range is $65 million.

	2017
	Low EPS			High EPS
(in millions, pre-tax)	guidance			guidance
GT&S revenue timing impact	~	$	160	~	$	160

Actual financial results for 2017 may differ materially from the guidance provided.  For a discussion of the factors that may affect future results, see the Forward-Looking Statements.

11

Use of Non-GAAP Financial Measures

PG&E Corporation and Pacific Gas and Electric Company

PG&E Corporation discloses historical financial results and provides guidance based on "earnings from operations" in order to provide a measure that allows investors to compare the underlying financial performance of the business from one period to another, exclusive of items impacting comparability.

"Earnings from operations" is a non-GAAP financial measure and is calculated as income available for common shareholders less items impacting comparability.  "Items impacting comparability" represent items that management does not consider part of the normal course of operations and affect comparability of financial results between periods, including certain pipeline related expenses, certain legal and regulatory related expenses, fines and penalties, Butte fire related costs, impacts of the 2015 GT&S rate case, and insurance recoveries for natural gas matters.  PG&E Corporation uses earnings from operations to understand and compare operating results across reporting periods for various purposes including internal budgeting and forecasting, short- and long-term operating planning, and employee incentive compensation.  PG&E Corporation believes that earnings from operations provide additional insight into the underlying trends of the business allowing for a better comparison against historical results and expectations for future performance.

Earnings from operations are not a substitute or alternative for GAAP measures such as consolidated income available for common shareholders and may not be comparable to similarly titled measures used by other companies.

12

EX-99.02

EXHIBIT 99.2

 THIRD QUARTER EARNINGS CALLNovember 4, 2016 

 Forward Looking Statements    This slide presentation contains forecasts and estimates of PG&E Corporation’s 2016 financial results, 2016 equity issuances and general earnings sensitivities. These forecasts and estimates are based on certain assumptions, including but not limited to those relating to Pacific Gas and Electric Company’s (Utility) authorized revenues, projected rate base, future expenses and capital expenditures, 2015 GT&S rate case, incremental equity factors, CPUC Penalty Decision, and other factors, which constitute forward-looking statements that are necessarily subject to various risks and uncertainties and actual results may differ materially. PG&E Corporation and the Utility are not able to predict all the factors that may affect future results. Factors that could cause actual results to differ materially include, but are not limited to: the timing and outcomes of the final CPUC decision in Phase 2 of the 2015 GT&S rate case, the 2017 GRC, the TO rate cases, and other ratemaking and regulatory proceedings; the timing and outcomes of the debarment proceeding and potential remedial and other measures that may be imposed on the Utility as a result of the debarment proceeding and the jury’s verdict in the federal criminal trial of the Utility (including a potential appointment of one or more independent third-party monitor(s)), the Utility’s motion for judgment of acquittal, the SED’s unresolved enforcement matters relating to the Utility’s compliance with natural gas-related laws and regulations, and other investigations that have been or may be commenced relating to the Utility’s compliance with natural gas-related laws and regulations; the timing and outcomes of (i) the CPUC’s investigation of communications between the Utility and the CPUC that may have violated the CPUC’s rules regarding ex parte communications or are otherwise alleged to be improper, and (ii) the U.S. Attorney’s Office in San Francisco and the California Attorney General’s office investigations in connection with communications between the Utility’s personnel and CPUC officials, and whether such matters negatively affect the final decisions to be issued in Phase 2 of the 2015 GT&S rate case and other ratemaking proceedings; the timing and outcomes of the Butte fire litigation, whether the Utility’s insurance is sufficient to cover the Utility’s liability resulting therefrom and otherwise available, and whether additional investigations and proceedings in connection with Butte fire will be opened;the Utility’s ability to control its costs within the authorized levels of spending and the extent to which the Utility incurs unrecoverable costs that are higher than the forecasts of such costs; changes in cost forecasts or the scope and timing of planned work resulting from changes in customer demand for electricity and natural gas or other reasons; the outcomes of the SED’s investigations of potential violations identified though audits, investigations, or self-reports; the impact that reductions in customer demand for electricity and natural gas have on the Utility’s ability to make and recover its investments through rates and earn its authorized return on equity, and whether the Utility is successful in addressing the impact of growing distributed and renewable generation resources and changing customer demand for natural gas and electric services; the amount and timing of charges reflecting probable liabilities for third-party claims, the extent to which costs incurred in connection with third-party claims or litigation can be recovered through insurance, rates, or from other third parties, and whether the Utility can continue to obtain insurance and whether insurance coverage is adequate for future losses or claims, especially following a major event that causes widespread third-party losses; the ability of PG&E Corporation and the Utility to access capital markets and other sources of debt and equity financing in a timely manner on acceptable terms, and the amount and timing of additional common stock and debt issuances by PG&E Corporation; changes in estimated environmental remediation costs, including costs associated with the Utility’s natural gas compressor sites; the outcome of federal or state tax audits and the impact of any changes in federal or state tax laws, policies, regulations, or their interpretation; the impact of changes in GAAP, standards, rules, or policies, including those related to regulatory accounting, and the impact of changes in their interpretation or application; andthe other factors disclosed in PG&E Corporation and the Utility’s joint Annual Report on Form 10-K for the year ended December 31, 2015 and Quarterly Reports on Form 10-Q for the quarters ended March 31, June 30, and September 30, 2016. This presentation is not complete without the accompanying statements made by management during the webcast conference call held on November 4, 2016. The statements in this presentation are made as of November 4, 2016. PG&E Corporation undertakes no obligation to update information contained herein. This presentation, including Appendices, and the accompanying press release were attached to PG&E Corporation’s Current Report on Form 8-K that was furnished to the Securities and Exchange Commission on November 4, 2016 and, along with the replay of the conference call, is also available on PG&E Corporation’s website at www.pgecorp.com.   2 

 Q3 2016 Earnings Results  Earnings from Operations is not calculated in accordance with GAAP and excludes items impacting comparability. See Appendix 2, Exhibit A for a reconciliation of Earnings per Share (“EPS”) from Operations to EPS on a GAAP basis and Exhibit G for the use of non-GAAP financial measures.   3 

 Q3 2016: Quarter over Quarter Comparison  4  Earnings from Operations is not calculated in accordance with GAAP and excludes items impacting comparability. See Appendix 2, Exhibit A for a reconciliation of Earnings per Share (“EPS”) from Operations to EPS on a GAAP basis and Exhibit G for the use of non-GAAP financial measures.  

 2016 Earnings Per Share Guidance  5  Guidance range excludes any potential future fines, penalties, or disallowances  Changes from prior quarter are noted in blue.   See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions.See Appendix 2, Exhibit E for detailed 2016 earnings guidance and Exhibit G for the use of non-GAAP financial measures.   2016 equity issuance expected to be ~$800 million 

 Assumptions for 2016  6  Return on Equity: 10.4% Equity Ratio: 52%  Authorized Cost of Capital*        Authorized Ratebase (weighted average) ($ billions)    Other Factors Affecting Earnings from Operations    Capital Expenditures($ millions)  (1) Includes ~$300M of estimated capital disallowance from April 9, 2015 Penalty Decision(2) Amounts previously reserved for limits on PSEP authorized spend  *CPUC authorized  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions.  Changes from prior quarter are noted in blue.  

 2016 Items Impacting Comparability  7  (1) “Pipeline related expenses” includes costs to identify and remove encroachments from transmission pipeline rights of way. The company spent ~$210 million on this work in 2013-2015.(2) Reflects the portion of Q3 billed revenues expected to be disallowed in the final Phase 2 GT&S decision; item will be updated after the final Phase 2 decision to reflect the full 2016 impact of the ex parte penalty.  Changes from prior quarter are noted in blue.   Guidance range excludes any potential future fines, penalties, or disallowances  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions.See Appendix 2, Exhibit E for detailed 2016 earnings guidance and Exhibit G for the use of non-GAAP financial measures.  

 Appendices 

 Appendix 1 – Guidance          Key Assumptions: 2015 GT&S Case  Slide 10    CPUC Penalty Decision in Gas Transmission Pipeline Investigations  Slide 11  9 

 10  Final revenues uncertain pending final Phase 2 decision; billing began August 1, 2016Undercollected revenues for revenue requirement increase in 2015 and 7 months of 2016 will be amortized over 36 monthsTiming for revenue recognition2016 – Recognize 29 months of undercollection: 5 months actual billed revenues plus 24 months of undercollected revenue amortization (collected in rates in 2017 and 2018)2017 – Recognize remaining 7 months of undercollected revenue amortization (collected in rates in 2019)  2011-2014 Capital Spend Above Authorized~$135 million permanently disallowed~$400 million in ratebase subject to audit with potential for future recovery (~$545 million before depreciation and deferred taxes)2015-2018 Capital Spend – Impairment of ~$55 million in spending in excess of cost caps  Final decision in 2016$850 million San Bruno penalty allocation: ~$690M capital, ~$160M expense  Revenue Recognition   Phase 2 Decision  Capital Disallowance        APPENDIX 1 – GUIDANCEKey Assumptions: 2015 GT&S Case 

 APPENDIX 1 – GUIDANCECPUC Penalty Decision in Gas Transmission Pipeline Investigations  11  The Penalty Decision disallows the Utility from recovering $850 million in costs associated with pipeline safety-related projects and programs that the CPUC will identify in a final Phase 2 decision to be issued in the Utility’s 2015 GT&S rate case. The Phase 2 proposed decision issued on November 1, 2016 allocates $689 million of the $850 million to capital expenditures and the remaining $161 million to expense.Future GT&S revenues will be reduced for these unrecovered expenses. In the Penalty Decision, the CPUC estimated that the Utility would incur $50 million to comply with the remedies specified in the Penalty Decision. This table does not reflect the Utility’s remedy-related costs already incurred nor the Utility’s estimated future remedy-related costs. These costs would be expensed as incurred.  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions. 

 Appendix 2 – Supplemental Earnings Materials        Exhibit A:   Reconciliation of PG&E Corporation’s Earnings from Operations to Consolidated Income Available for Common Shareholders in Accordance with GAAP  Slides 13-14  Exhibit B:  Key Drivers of PG&E Corporation’s Earnings per Common Share from Operations  Slide 15  Exhibit C:  Operational Performance Metrics  Slides 16-17  Exhibit D:  Sales and Sources Summary  Slide 18  Exhibit E:  PG&E Corporation’s 2016 Earnings Per Share Guidance  Slides 19-20  Exhibit F:  2016 General Earnings Sensitivities  Slide 21  Exhibit G:  Use of Non-GAAP Financial Measures  Slide 22  Exhibit H:  Expected Timelines of Selected Regulatory Cases  Slides 23-28  12 

 Exhibit A: Reconciliation of PG&E Corporation’s Earnings from Operations to Consolidated Income Available for Common Shareholders in Accordance with Generally Accepted Accounting Principles (“GAAP”)   13  All amounts presented in the table above are tax adjusted at PG&E Corporation’s tax rate of 40.75 percent except for fines, which are not tax deductible. See Footnote 5 below.“Earnings from operations” is a non-GAAP financial measure. See Exhibit G: Use of Non-GAAP Financial Measures.“Items impacting comparability” represent items that management does not consider part of the normal course of operations and affect comparability of financial results between periods. See Exhibit G: Use of Non-GAAP Financial Measures. The Utility incurred costs of $31 million (before the tax impact of $13 million) and $80 million (before the tax impact of $33 million), during the three and nine months ended September 30, 2016, respectively, for pipeline related expenses incurred in connection with the multi-year effort to identify and remove encroachments from transmission pipeline rights of way.The Utility incurred costs of $23 million (before the tax impact of $9 million) and $54 million (before the tax impact of $22 million), during the three and nine months ended September 30, 2016, respectively, for legal and regulatory related expenses incurred in connection with various enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory communications. The Utility incurred costs of $67 million (before the tax impact of $25 million) and $327 million (before the tax impact of $121 million), during the three and nine months ended September 30, 2016, respectively, associated with fines and penalties. This includes costs of $59 million (before the tax impact of $23 million) and $294 million (before the tax impact of $119 million), during the three and nine months ended September 30, 2016, respectively, associated with estimated safety-related cost disallowances imposed by the CPUC in its April 9, 2015 decision (“San Bruno Penalty Decision”) in the gas transmission pipeline investigations. Specific projects to be disallowed will be determined in the CPUC’s phase two decision of the 2015 Gas Transmission and Storage (“GT&S”) rate case. The Utility also recorded $4 million (before the tax impact of $2 million), during the three and nine months ended September 30, 2016, for probable disallowances that will be imposed by the CPUC in its phase two decision of the 2015 GT&S rate case for prohibited ex parte communications. In addition, the Utility accrued fines of $1 million and $26 million, during the three and nine months ended September 30, 2016, respectively, in connection with the modified presiding officer’s decision approved by the CPUC on August 16, 2016 in its investigation regarding natural gas distribution record-keeping practices and $3 million, during the three and nine months ended September 30, 2016, in connection with the maximum statutory fine that may be imposed as a result of the jury verdict returned on August 9, 2016 in the federal criminal trial against the Utility. These fines are not tax deductible.  Page 1 of 2 

 Exhibit A: Reconciliation of PG&E Corporation’s Earnings from Operations to Consolidated Income Available for Common Shareholders in Accordance with Generally Accepted Accounting Principles (“GAAP”)   14  Page 2 of 2  Future fines or penalties may be imposed in connection with other enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory communications.The Utility incurred costs of $16 million (before the tax impact of $7 million) and $186 million (before the tax impact of $76 million), during the three and nine months ended September 30, 2016, respectively, associated with the Butte fire, net of insurance. This includes accrued charges of $350 million (before the tax impact of $143 million), during the nine months ended September 30, 2016, related to estimated third-party claims in connection with the Butte fire, partially offset by $260 million (before the tax impact of $106 million) recorded during the nine months ended September 30, 2016, as probable of insurance recovery. No additional charges or insurance recoveries related to estimated third-party claims were recognized in the three months ended September 30, 2016. The Utility also incurred charges of $16 million (before the tax impact of $7 million) and $96 million (before the tax impact of $39 million), during the three and nine months ended September 30, 2016, respectively, for Utility clean-up, repair, and legal costs associated with the Butte fire.  The Utility incurred charges of $190 million (before the tax impact of $77 million), during the nine months ended September 30, 2016, for capital expenditures that the Utility believes are probable of disallowance based on the CPUC phase one decision dated June 23, 2016 in the 2015 GT&S rate case, including $134 million (before the tax impact of $54 million) for a portion of the 2011 through 2014 capital expenditures in excess of adopted amounts and $56 million (before the tax impact of $23 million) for the Utility’s estimate of 2015 through 2018 capital expenditures that are probable of exceeding authorized amounts. No additional charges were recognized in the three months ended September 30, 2016. “GT&S revenue timing impact” refers to the revenues that are expected to be recorded in excess of the 2016 authorized revenue requirements after the CPUC issues a final phase two decision in the 2015 GT&S rate case to address the allocation of the $850 million disallowance for safety-related work adopted in the San Bruno Penalty Decision. Due to the uncertainty regarding the revenue requirement the CPUC will ultimately adopt, the Utility will not be able to record a true-up of revenues under-collected since January 1, 2015 until after a final phase two decision is issued. Represents insurance recoveries of $10 million (before the tax impact of $4 million) and $49 million (before the tax impact of $20 million) for third-party claims and associated legal costs that the Utility received in connection with the San Bruno accident during the three and nine months ended September 30, 2015, respectively. No further insurance recoveries related to the San Bruno accident are expected. 

 Exhibit B: Key Drivers of PG&E Corporation’s Earnings per Common Share (“EPS”) from Operations  15  Third Quarter and YTD, 2016 vs. 2015($/Share, Diluted)  See Exhibit A for a reconciliation of EPS from Operations to EPS on a GAAP basis. All amounts presented in the table above are tax adjusted at PG&E Corporation’s tax rate of 40.75 percent.Represents the incremental authorized revenue collected through rates beginning August 1, 2016 in accordance with the final phase one decision in the Utility’s 2015 GT&S rate case during the three and nine months ended September 30, 2016.Represents the gain recognized during the three months ended March 31, 2015. No comparable gain was recognized for the same period in 2016. 

 Exhibit C: Operational Performance Metrics  16  See following page for definitions of the operational performance metrics. The operational performance goals set under the PG&E Corporation 2016 Short Term Incentive Plan (“STIP”) are based on the same operational metrics and targets.  The 2016 target for earnings from operations is not publicly reported but is consistent with the guidance range provided for 2016 EPS from operations of $3.65 to $3.85.   2016 Year to Date 

 Definitions of 2016 Operational Performance Metrics from Exhibit C  17  SafetyPublic and employee safety are measured in four areas: (1) Nuclear Operations Safety, (2) Gas Operations Safety, (3) Electric Operations Safety, and (4) Employee Safety.The safety of the Utility’s nuclear power operations, Unit 1 and Unit 2, is an index comprised of 12 performance indicators for nuclear power generation that are regularly benchmarked against other nuclear power generators. The safety of the Utility’s electric operations is represented by (a) the percentage improvement in the number of wire down events with resulting unplanned sustained outages compared to the same report period of the previous year, and (b) the percentage of time that Utility personnel are on site within 60 minutes after receiving a 911 call of a potential Utility electric hazard.The safety of the Utility’s natural gas operations is represented by (a) the ability to complete planned in-line inspections and pipeline retrofit projects, measured by two equally weighted components of In-Line Inspections and In-Line Upgrades; (b) the number of third party “dig-ins” (i.e., damage resulting in repair or replacement of underground facility) to Utility gas assets per 1,000 Underground Service Alert tickets; and (c) the timeliness (measured in minutes) of on-site response to gas emergency service calls.The safety of the Utility’s employees is represented by (a) the number of lost workday cases incurred per 200,000 hours worked (or for approximately every 100 employees), (b) the number of serious preventable motor vehicle incidents that the driver could have reasonably avoided, per one million miles driven, and (c) the percentage of work-related injuries reported to the 24/7 Nurse Report Line within one day of the incident. CustomerCustomer satisfaction and service reliability are measured by:The overall satisfaction (measured as a score of zero to 100) of customers with the products and services offered by the Utility, as measured through a quarterly survey performed by an independent third-party research firm.The total time (measured in minutes) the average customer is without electric power during a given time period.FinancialEarnings from Operations (shown in millions of dollars) measures PG&E Corporation’s earnings power from ongoing core operations. They allow investors to compare the underlying financial performance of the business from one period to another, exclusive of items that management believes do not reflect the normal course of operations (items impacting comparability). Earnings from Operations are not calculated in accordance with GAAP. For a reconciliation of Earnings from Operations to Consolidated Income Available for Common Shareholders as reported in accordance with GAAP, see Exhibit A. 

 Exhibit D: Pacific Gas and Electric Company Sales and Sources Summary  18  Third Quarter and Year to Date, 2016 vs. 2015  Includes other sources of electric energy totaling 2,782 kWh and 2,169 kWh for the three months ended September 30, 2016 and 2015, respectively, and 6,748 kWh and 5,801 kWh for the nine months ended September 30, 2016 and 2015, respectively.   Please see the 2015 Annual Report on Form 10-K for additional information about operating statistics. 

 Exhibit E: PG&E Corporation’s 2016 Earnings per Share Guidance  19  All amounts presented in the table above are tax adjusted at PG&E Corporation’s tax rate of 40.75 percent except for fines, which are not tax deductible. See Footnote 5 below.“Earnings from operations” is a non-GAAP financial measure. See Exhibit G: Use of Non-GAAP Financial Measures.“Items impacting comparability” represent items that management does not consider part of the normal course of operations and affect comparability of financial results between periods. See Exhibit G: Use of Non-GAAP Financial Measures.“Pipeline related expenses” includes costs incurred to identify and remove encroachments from transmission pipeline rights-of-way. The pre-tax range of estimated costs is shown below. The offsetting tax impacts for the low and high EPS guidance range are $61 million and $41 million, respectively.“Legal and regulatory related expenses” includes costs incurred in connection with various enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory communications. The pre-tax range of estimated costs is shown below. The offsetting tax impact for the low and high EPS guidance range is $31 million.“Fines and penalties” includes actual and estimated future fines and penalties resulting from various enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory communications. Guidance of $449 million is consistent with the estimated 2016 components of the $1.6 billion San Bruno Penalty Decision in the gas transmission pipeline investigations. Guidance reflects amounts recorded during the nine months ended September 30, 2016 related to probable disallowances that will be imposed by the CPUC in its phase two decision of the 2015 GT&S rate case for prohibited ex parte communications. Guidance is also consistent with the non-tax-deductible $26 million fine accrued in connection with the CPUC decision in its investigation regarding natural gas distribution record-keeping practices and the non-tax-deductible $3 million fine accrued in connection with the maximum statutory fine that may be imposed as a result of the jury verdict returned on August 9, 2016 in the federal criminal trial against the Utility. Guidance does not include amounts for other potential future fines or penalties. The pre-tax range of estimated costs is shown below. The offsetting tax impact for the low and high EPS guidance range is $171 million.  Page 1 of 2 

 Exhibit E: PG&E Corporation’s 2016 Earnings per Share Guidance  20  “Butte fire related costs, net of insurance” includes charges of $446 million (before the tax impact of $182 million) recorded for the nine months ended September 30, 2016 related to estimated third-party claims and Utility clean-up, repair, and legal costs associated with the Butte fire. Guidance is consistent with $350 million corresponding to the low end of the estimated range of costs related to third-party claims. The Utility currently is unable to estimate the high end of the range. This amount is partially offset by $260 million (before the tax impact of $106 million) accrued as probable of insurance recovery for the nine months ended September 30, 2016. The pre-tax range of estimated costs is shown below. The offsetting tax impact for the low and high EPS guidance range is $76 million.“GT&S capital disallowance” includes capital expenditures that the Utility believes are probable of disallowance based on the CPUC phase one decision dated June 23, 2016 in the 2015 GT&S rate case, including $134 million (before the tax impact of $54 million) for a portion of the 2011 through 2014 capital expenditures in excess of adopted amounts and $56 million (before the tax impact of $23 million) for the Utility’s estimate of 2015 through 2018 capital expenditures that are probable of exceeding authorized amounts. The pre-tax range of estimated costs is shown below. The offsetting tax impact for the low and high EPS guidance range is $77 million.“GT&S revenue timing impact” refers to the revenues that are expected to be recorded in excess of the 2016 authorized revenue requirements after the CPUC issues a final phase two decision in the 2015 GT&S rate case to address the allocation of the $850 million disallowance for safety-related work adopted in the San Bruno Penalty Decision. Due to the uncertainty regarding the revenue requirement the CPUC will ultimately adopt in the final phase two decision, the Utility will not be able to record a true-up of revenues under-collected since January 1, 2015 until after the final phase two decision is issued. In addition, accounting rules allow the Utility to recognize revenues in a given year only if they will be collected from customers within 24 months of the end of that year. Because the phase one decision directs the Utility to collect the difference between the adopted “interim” revenue requirements and the amounts previously collected in rates, retroactive to January 1, 2015, over a 36-month period, the Utility will complete recording the full true-up of under-collected revenues in 2017. The pre-tax range of estimated revenues is shown below. The offsetting tax impact for the low and high EPS guidance range is $143 million.  Page 2 of 2  Actual financial results for 2016 may differ materially from the guidance provided. For a discussion of factors that may affect future results, see the Forward-Looking Statements. 

 Exhibit F: 2016 General Earnings SensitivitiesPG&E Corporation and Pacific Gas and Electric Company  21  These general earnings sensitivities on factors that may affect 2016 earnings are forward-looking statements that are based on various assumptions. Actual results may differ materially. For a discussion of factors that may affect future results, see the Forward-Looking Statements. 

 Exhibit G: Use of Non-GAAP Financial Measures  22  PG&E Corporation and Pacific Gas and Electric Company: Use of Non-GAAP Financial MeasuresPG&E Corporation discloses historical financial results and provides guidance based on “earnings from operations” in order to provide a measure that allows investors to compare the underlying financial performance of the business from one period to another, exclusive of items impacting comparability. “Earnings from operations” is a non-GAAP financial measure and is calculated as income available for common shareholders less items impacting comparability. “Items impacting comparability” represent items that management does not consider part of the normal course of operations and affect comparability of financial results between periods, including certain pipeline related expenses, certain legal and regulatory related expenses, fines and penalties, Butte fire related costs, net of insurance, and impacts of the 2015 GT&S rate case. PG&E Corporation uses earnings from operations to understand and compare operating results across reporting periods for various purposes including internal budgeting and forecasting, short- and long-term operating planning, and employee incentive compensation. PG&E Corporation believes that earnings from operations provide additional insight into the underlying trends of the business allowing for a better comparison against historical results and expectations for future performance. Earnings from operations are not a substitute or alternative for GAAP measures such as consolidated income available for common shareholders and may not be comparable to similarly titled measures used by other companies.  

 Exhibit H: Pacific Gas and Electric CompanyExpected Timelines of Selected Regulatory Cases  23 

 Exhibit H: Pacific Gas and Electric CompanyExpected Timelines of Selected Regulatory Cases  24 

 Exhibit H: Pacific Gas and Electric CompanyExpected Timelines of Selected Regulatory Cases  25 

 Exhibit H: Pacific Gas and Electric CompanyExpected Timelines of Selected Regulatory Cases  26 

 Exhibit H: Pacific Gas and Electric CompanyExpected Timelines of Selected Regulatory Cases  27 

 Exhibit H: Pacific Gas and Electric CompanyExpected Timelines of Selected Regulatory Cases  28 

EX-99.03

EXHIBIT 99.3

 BUSINESS UPDATENovember 4, 2016 

 Forward Looking Statements    This slide presentation contains forecasts and estimates of PG&E Corporation’s 2017 financial results and equity issuances, capital expenditures to be made by PG&E Corporation’s subsidiary, Pacific Gas and Electric Company (Utility) through 2019, the Utility’s rate base through 2019, dividend policy, future investments, and general earnings sensitivities. These forecasts and estimates are based on certain assumptions, including but not limited to those relating to the Utility’s authorized revenues, future expenses and capital expenditures, 2015 GT&S rate case, equity issuance factors, and other factors, which constitute forward-looking statements that are necessarily subject to various risks and uncertainties and actual results may differ materially. PG&E Corporation and the Utility are not able to predict all the factors that may affect future results. Factors that could cause actual results to differ materially include, but are not limited to: : the timing and outcomes of the final CPUC decision in Phase 2 of the 2015 GT&S rate case, the 2017 GRC, the TO rate cases, and other ratemaking and regulatory proceedings; the timing and outcomes of the debarment proceeding and potential remedial and other measures that may be imposed on the Utility as a result of the debarment proceeding and the jury’s verdict in the federal criminal trial of the Utility (including a potential appointment of one or more independent third-party monitor(s)), the Utility’s motion for judgment of acquittal, the SED’s unresolved enforcement matters relating to the Utility’s compliance with natural gas-related laws and regulations, and other investigations that have been or may be commenced relating to the Utility’s compliance with natural gas-related laws and regulations; the timing and outcomes of (i) the CPUC’s investigation of communications between the Utility and the CPUC that may have violated the CPUC’s rules regarding ex parte communications or are otherwise alleged to be improper, and (ii) the U.S. Attorney’s Office in San Francisco and the California Attorney General’s office investigations in connection with communications between the Utility’s personnel and CPUC officials, and whether such matters negatively affect the final decisions to be issued in Phase 2 of the 2015 GT&S rate case and other ratemaking proceedings; the timing and outcomes of the Butte fire litigation, whether the Utility’s insurance is sufficient to cover the Utility’s liability resulting therefrom and otherwise available, and whether additional investigations and proceedings in connection with Butte fire will be opened;the Utility’s ability to control its costs within the authorized levels of spending and the extent to which the Utility incurs unrecoverable costs that are higher than the forecasts of such costs; changes in cost forecasts or the scope and timing of planned work resulting from changes in customer demand for electricity and natural gas or other reasons; the outcomes of the SED’s investigations of potential violations identified though audits, investigations, or self-reports; the impact that reductions in customer demand for electricity and natural gas have on the Utility’s ability to make and recover its investments through rates and earn its authorized return on equity, and whether the Utility is successful in addressing the impact of growing distributed and renewable generation resources and changing customer demand for natural gas and electric services; the amount and timing of charges reflecting probable liabilities for third-party claims, the extent to which costs incurred in connection with third-party claims or litigation can be recovered through insurance, rates, or from other third parties, and whether the Utility can continue to obtain insurance and whether insurance coverage is adequate for future losses or claims, especially following a major event that causes widespread third-party losses; the ability of PG&E Corporation and the Utility to access capital markets and other sources of debt and equity financing in a timely manner on acceptable terms, and the amount and timing of additional common stock and debt issuances by PG&E Corporation; changes in estimated environmental remediation costs, including costs associated with the Utility’s natural gas compressor sites; the outcome of federal or state tax audits and the impact of any changes in federal or state tax laws, policies, regulations, or their interpretationthe impact of changes in GAAP, standards, rules, or policies, including those related to regulatory accounting, and the impact of changes in their interpretation or application; and the other factors disclosed in PG&E Corporation and the Utility’s joint Annual Report on Form 10-K for the year ended December 31, 2015 and Quarterly Reports on Form 10-Q for the quarters ended March 31, June 30, and September 30, 2016. This presentation is not complete without the accompanying statements made by management during the webcast conference call held on November 4, 2016. The statements in this presentation are made as of November 4, 2016. PG&E Corporation undertakes no obligation to update information contained herein. This presentation, including Appendices, and the accompanying press release were attached to PG&E Corporation’s Current Report on Form 8-K that was furnished to the Securities and Exchange Commission on November 4, 2016 and, along with the replay of the conference call, is also available on PG&E Corporation’s website at www.pgecorp.com.   2 

       Well-positioned to Deliver Strong Returns  A Strengthened Company  Key Advantages  Robust Growth Profile  Significant safety, reliability and operational improvementsImproved customer satisfaction  One of the greenest utilities in the countryConstructive regulatory and policy environmentMultiple infrastructure investment drivers  State policies support strong cap ex and ratebase growthResumed dividend growth     See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions.  Healthy 3-year growth profile~6.5-7% ratebase growthAbove average dividend growth  3 

 Agenda  4  Key advantages  Robust growth profile  A strengthened company     

 PG&E System At a Glance  5  Key Highlights  2015 Revenue Sources  Employees  Californians served  Net income (2015)  Ratebase (2015)  Miles of electric lines  MW utility-owned generation  GWh electricity generated and procured  ~23,000  ~16M  ~$1B  $29.5B  ~160,000  ~7,700  ~72,000  Miles of natural gas pipelines  ~50,000  Carbon-free and renewable energy delivered  ~60% 

         Safety Forms the Foundation of Operationaland Financial Success  6  50% of short-term variable compensation tied to safety performance  Developed industry-leading public safety dashboard  Significant utility leadership experience on the Board and executive team  Embraced a continuous improvement mindset and speak-up culture  Demonstrated commitment to safety and compliance at all levels  Strong Operational and Financial Results  Transparency  Leadership  Incentives  Culture 

   Improved Safety and ReliabilityGas Metrics  (1) Emergency response time recorded in minutes; (2) Open Grade 2 and 2+ leaks; (3) Third party damages per 1,000 Underground Service Alert (USA) tickets.  7  Major Progress from 2010-2015:Achieved international certifications in gas safety excellence programsReplaced 490+ miles of transmission and distribution pipelineHydrotested 750+ miles of transmission pipelineMade 690+ miles transmission pipeline capable of in-line inspectionInstalled 235 automated valves  12,200  >99% Reduction in Leak Backlog(2)  3.5  2.1  40% Reduction in Dig-ins(3)  94  ~40% Reduction in EmergencyResponse Time(1)   20.3  33.3    ~40%    >99%    40% 

   Improved Safety and Reliability Electric Metrics  (1) Percentage of time PG&E personnel are on-site within 60 minutes of receiving a 911 electric-related call; (2) Average outage duration experienced by all customers served measured in minutes; (3) Percentage of customers experiencing 5 or more sustained interruptions over the past rolling 12 months (includes both planned & unplanned outages).  8  Major Progress from 2010-2015:Delivered 7 Years of record-setting electric reliability~$11 billion investment in transmission and distribution asset enhancementsCompleted deployment of ~10 million SmartMetersUpgraded ~70% of our targeted circuits  1Q  96%  911 Emergency Response(1)  65%  3Q  3Q  2Q  157.2  96.3  System Average Interruption Duration Index(2)  2Q  1Q  Customer Experiencing Multiple Interruptions(3)  3.31%  1.36%    ~50%    ~40%    ~60% 

 Customer Satisfaction has Improved Each Year Since 2012  9  Electric Residential2nd Quartile  Gas Residential4th Quartile  Electric Business2nd Quartile  Gas Business2nd Quartile  J.D. Power Survey Results, 2011-2016  Unwavering commitment to customer satisfaction 

 Projected Strong Growth  10  Ratebase ($ in B)  ~6.5-7% CAGR  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions. 

 Agenda  11  Key advantages  Robust growth profile  A strengthened company     

 Key Strengths  12    1  One of the greenest utilities in the country    2    3  Constructive regulatory framework    4  California clean energy policies  Multiple infrastructure investment drivers 

 KEY STRENGTH #1: ONE OF THE GREENEST UTILITIES IN THE COUNTRYFocused on Sustainability  13          58%  32%  Nearly 2x More Carbon Free and Renewable Energy Than The U.S. Average in 2015  Sustainability Advisory Council established in 2015   PG&E Customers Lead the Nation in Clean Technology Adoption        ~800 GWh/yr of efficiency savingsRanked #2 among U.S. utilities  >280,000 solar customersRanked #1 with ~25% of all U.S. rooftop solar  Nearly 100,000 electric vehicles Ranked #1 with ~20% of all U.S. vehicles     Extensive Third Party Recognition   

 KEY STRENGTH #2: CONSTRUCTIVE REGULATORY FRAMEWORKCalifornia’s Regulatory Mechanisms  14  PG&E’s industry-leading risk management aligns with CPUC safety focus  Revenues decoupled from salesBalancing accounts reduce cost volatilityForward-looking test year rate casesRisk-informed rate makingSeparate cost of capital proceeding    ü    ü    ü    ü    ü   

 KEY STRENGTH #3: CALIFORNIA CLEAN ENERGY POLICIES California’s Climate Goals  15      California is Targeting:  50%renewables by 2030  1.5Melectric vehicles by 2025    2Xenergy efficiencyin existing buildings by 2030  California Greenhouse Gas Reduction Goals and Historic Emissions*  PG&E is a critical partner in achieving California’s clean energy goals  *Source: California Air Resources Board  Ag. & Forestry  Res. & Comm.  Transportation 

       Key Strength #4: Multiple INFRASTRUCTURE INVESTMENT DriversCalifornia Policies Drive Infrastructure Investment   Gas investments (e.g., pipeline replacement, in-line inspection capability)Electric investments (e.g., substation upgrades, cable upgrades)Generation asset upgrades  Grid modernizationRenewable integration projectsEnergy efficiency programsEnergy storage optionsElectric vehicle infrastructureState infrastructure modernization (e.g., rail and water projects)  16  Safetyand Reliability  Enabling California’s Clean Energy Economy  Sustained Investments           

 Agenda  17  Key advantages  Robust growth profile  A strengthened company     

 Focus Areas for Growth  18  PG&E’s operating plan provides a strong foundation for future success  Enhance safety and reliability  1  Enable California’s clean energy economy  2  Ensure customer affordability  3 

 GROWTH FOCUS #1: ENHANCE SAFETY AND RELIABILITYContinue to Upgrade Our System  19  Investments to systematically modernize infrastructure  19  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions. 

 GROWTH FOCUS #2: ENABLE CALIFORNIA’S CLEAN ENERGY ECONOMYGrid Modernization Will Require Significant Investment  20  Grid Storage Enables renewable integration  Grid Control and MonitoringIncreased remote control and sensor technology reduce outages and enable self-healing grid  Grid Data AnalyticsAdvanced analytics enhance decision making, improve operations and reduce cost  Distributed Energy ResourcesBi-directional energy flows and voltage fluctuations require integration investments  Energy Efficiency and Demand ResponseHelp manage customer costs  Electric VehiclesRequires expanded infrastructure  Increased RenewablesRequires transmission integration  ~$1 billion in planned grid modernization investments through 2020  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions. 

 GROWTH FOCUS #3: ENSURE CUSTOMER AFFORDABILITYPG&E Bills Lower Than the National Average  21  Continued focus on keeping customer bills affordable 

 22  GROWTH FOCUS #3: ENSURE CUSTOMER AFFORDABILITYStrategies to Manage Declining Load  Flexible Electric Portfolio  Utility-Owned Generation ~45%  Procured~55%  ~30% of procuredMWhs expireby 2021    Constructive Regulatory Mechanisms  Revenues decoupled from salesCost allocation mechanisms for departing customers  Modernizing Rate Structures  Focus on Continuous Improvement  Residential Rate Design  Time of Use Rates  Fixed/ Demand Charges   Net Energy Metering  CPUC Distributed Energy Resources Action Plan                ProcurementEfficiencies  Leveraging Technology  Process Standardization  Sustainable Efficiencies    ü    ü         

 GOING FORWARDWell-Positioned for Industry Changes  23  Industry Changes  PG&E Strategies  Decarbonized Economy  Customer Choice  Integrate renewables and distributed energy resources Enable electric vehicle adoptionExpand energy storage optionsEnhance energy efficiency programs  Flexible procurement portfolioConstructive regulatory mechanisms Modernize rate structuresSustainable efficiencies     

 Three-year Financial Outlook  24  2017 Guidance  1  Cap ex growth  2  Dividend growth and policy  4  Ratebase growth  3 

 Initiating 2017 EPS Guidance  25  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions. See Appendix 2, PG&E Corporation’s 2017 Earnings per Share Guidance and Use of Non-GAAP Financial Measures. 

 2017 Assumptions   Return on Equity: 10.4% Equity Ratio: 52%  Authorized Cost of Capital*    Authorized Ratebase (weighted average) ($ billions)    Other Factors Affecting Earnings from Operations  Capital Expenditures($ millions)  *CPUC authorized  26  +/- GRC settlement approved without material change+/- GT&S Phase 2 PD approved without material change- GT&S amounts not requested+ Incentive revenues and other benefitsCWIP earnings: offset by below-the-line costs   See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions.         

 2017 Items Impacting Comparability  Items Impacting Comparability range excludes a disallowance that will be imposed in the final Phase 2 2015 GT&S decision for prohibited ex parte communications, and any additional potential future fines or penalties  27  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions. See Appendix 2, PG&E Corporation’s 2017 Earnings per Share Guidance and Use of Non-GAAP Financial Measures. 

 2017 Equity Issuance  28  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions. 

 Robust Cap Ex Supports Strong Returns  29  Capital Expenditures ($ in B) 2016-2019  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions. 

 Ratebase Supports Strong Returns  30  Base Case Assumptions:2017 General Rate Case settlement through 20192015 Gas Transmission & Storage rate casePhase 2 PD through 2018; flat in 2019~$400M for 2011-2014 spend subject to audit added in 2018 Transmission Owner rate case:High end: TO18 filing held flat through 2019Low end: TO17 settlement held flat through 2019 Electric vehicle infrastructure settlement approved in 2016  Potential Future Updates: 2019 Gas Transmission & Storage rate case2018 and 2019 Transmission Owner rate casesFuture competitive transmission opportunitiesState infrastructure modernization (e.g., rail and water projects)Future storage opportunities  Weighted Average Ratebase ($ in B)2016-2019  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions. 

 Dividend Policy Supports Strong Total Shareholder Return  31  Targeting 55-65% payout ratio over time  See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions. 

       IN SUMMARYSolid Growth Strategy Positions PG&E for Success  A Strengthened Company  Key Advantages  Robust Growth Profile  Significant safety, reliability and operational improvementsImproved customer satisfaction  One of the greenest utilities in the countryConstructive regulatory and policy environmentMultiple infrastructure investment drivers  State policies support strong cap ex and ratebase growthResumed dividend growth   Healthy 3-year growth profile~6.5-7% ratebase growthAbove average dividend growth    See the Forward Looking Statements for factors that could cause actual results to differ materially from the guidance presented and underlying assumptions.  32 

 Appendices 

 Table of Contents      Appendix 1: Leadership Bios  Slides 35 – 44  Appendix 2: 2017 Supplemental Earnings Materials  Slides 45 – 48  Appendix 3: Overview of Key Regulatory Cases  Slides 49 – 57  Appendix 4: Breakdown of 2015 Total Revenue Requirement  Slide 58  Appendix 5: Description of Gas System Certifications  Slide 59  Appendix 6: Credit Metrics and Ratings  Slide 60  34 

 APPENDIX 1 – LEADERSHIP BIOS Anthony F. Earley, Jr.  35  Anthony F. Earley, Jr.Chairman, Chief Executive Officer, and PresidentPG&E CorporationAnthony F. Earley, Jr., is Chairman, Chief Executive Officer, and President of PG&E Corporation. Earley joined PG&E in September 2011 after 17 years at DTE Energy, where he served as Executive Chairman, Chairman, and Chief Executive Officer.Since joining PG&E, Earley has spearheaded major initiatives related to safety culture, operational excellence, long-term integrated planning, and workforce development. Under Earley's leadership, PG&E has experienced the highest reliability in its over 150-year history. PG&E also continues to grow its environmentally friendly generation portfolio, with more than 50 percent of its assets having no carbon emissions.As former chairman of the Edison Electric Institute (EEI), the trade association of investor utilities, Earley was directly involved in the development of national policies on energy, the environment, and climate change issues. In 2014, Earley received EEI's Distinguished Leadership Award for his decades of contributions to the electric power industry. He also served as chair of the Nuclear Energy Institute and worked to revitalize the U.S. nuclear industry.Earley earned a Bachelor of Science degree in physics, a Master of Science degree in engineering, and a law degree at the University of Notre Dame, where he serves on the advisory council of the College of Engineering. After graduating from Notre Dame, Earley went on to serve as an officer in the United States Navy nuclear submarine program, where he was qualified as a chief engineer officer. He joined DTE Energy as president and chief operating officer in March 1994. Prior to joining DTE Energy, Earley served in various capacities at Long Island Lighting Company, including president and chief operating officer. He was also a partner at the Hunton & Williams law firm.Earley serves on the executive committees of the Edison Electric Institute and the Nuclear Energy Institute and is a board member of the Electric Power Research Institute. He is also on the board at Ford Motor Company.His commitment to the community includes memberships on the boards of United Way Bay Area, The Exploratorium, a science, arts, and human perception museum based in San Francisco, and the Bay Area Council. Earley was named 2015 Philanthropic CEO of the Year by the American Red Cross of the Bay Area. His community service was also recognized by readers of The Detroit News, and in 2003 he was selected as one of the several Michiganians of the Year. 

 Nick StavropoulosPresident, GasPacific Gas and Electric CompanyNick Stavropoulos serves as President, Gas, for Pacific Gas and Electric Company and has more than 35 years of experience in the U.S. and international gas industry. He is a member of the utility's board of directors and also oversees PG&E's enterprise IT; physical & cyber security; safety, health & environmental; supply chain; and transportation/fleet/real estate organizations. He was drawn to the Bay Area and PG&E in 2011 to lead the multi-billion dollar recovery and restoration effort to enhance the company's gas system after a gas transmission pipeline explosion in San Bruno, Calif.Today, he and his team are responsible for the end-to-end delivery of safe, reliable, affordable and clean gas service to 16 million people across PG&E's 70,000 square mile service area in northern and central California. Stavropoulos is a passionate advocate for workplace safety and safety culture. Since joining PG&E, he has championed independent, third party verification of the company's gas system from a number of different global organizations. Under his leadership, PG&E's gas business has earned or qualified for international certifications including ISO 55000; PAS 55001; and API 1173. PG&E is the only North American utility to currently hold these third party certifications.Prior to joining PG&E, Stavropoulos served as Executive Vice President and Chief Operating Officer for National Grid, an electricity and natural gas delivery company serving nearly seven million customers in the Northeast United States. It also operates the systems that deliver gas and electricity across Great Britain. As COO, he was responsible for all aspects of its U.S. gas distribution business. Prior to that role, Stavropoulos was President of KeySpan Energy Delivery. Throughout his career, he held a number of different senior leadership positions with successive levels of responsivity at Keyspan's predecessor companies - Colonial Gas Company and Boston Gas.Stavropoulos is an internationally sought after keynote speaker on the topics of leadership and safety culture. In recent years, he has delivered speeches at the International Atomic Energy Agency in Vienna, Austria; the National Safety Council's Campbell Institute in Austin, Texas; the Institute of Engineering and Technology/The Institute of Asset Management Conference in London, United Kingdom; the International Safety Culture Symposium in Halifax, Canada; and the Global Safety Culture Conference, Nashville; Tennessee.A native New Englander, Stavropoulos holds a Bachelor of Science degree in accounting from Bentley College and earned his Master in Business Administration from Babson College. He sits on the board of his alma mater Bentley University. He has served on multiple public and not-for-profit boards including chairing audit committees. He lives in San Francisco and is an avid Soul Cycler.  APPENDIX 1 – LEADERSHIP BIOS Nick Stavropoulos   36 

 APPENDIX 1 – LEADERSHIP BIOS Geisha J. Williams  37  Geisha J. WilliamsPresident, ElectricPacific Gas and Electric CompanyGeisha J. Williams has been President, Electric, at Pacific Gas and Electric Company since 2015 and is a member of the utility’s board of directors. Williams has more than three decades of experience in the utility industry. Williams and her team are responsible for the end-to-end delivery of safe, reliable, affordable and clean electricity to 16 million people in northern and central California. Her focus on renewables integration, grid modernization and smart grid technologies has resulted in PG&E customers benefitting from the best electric reliability in company history while also receiving energy that is nearly 60 percent greenhouse gas free. Beyond her electric responsibilities, Williams has enterprise-wide responsibility for customer service, emergency preparedness and response, and energy procurement. Williams joined PG&E in 2007 and was named Executive Vice President for Electric Operations in 2011.Before joining PG&E, Williams worked at Florida Power and Light (FPL) for 24 years. She served in a number of roles during her tenure there including Vice President of Power Systems, Electric Distribution. In this role, she was responsible for all aspects of the electric distribution infrastructure serving FPL’s 4.4 million customers, including asset management and planning, engineering, construction, maintenance and restoration. During her time at FPL, she considers the company’s restoration and recovery efforts in response to seven hurricanes that made landfall in a 15-month period as one of her proudest accomplishments.Williams is a director at the Edison Electric Institute, the Institute of Nuclear Power Operations, and the Association of Edison Illuminating Companies. She also serves as the board chair for the Center for Energy Workforce Development and is an active participant in Executive Women in Energy.Her involvement with the community includes serving as a trustee of the California Academy of Sciences and a member of the University of Miami President’s Council. She is a five-time recipient of the Bay Area Most Influential Women in Business Award, and in 2014 she was honored with Leadership California’s Trailblazer Award. Williams holds a bachelor's degree in engineering from the University of Miami and a master’s degree in business administration from Nova Southeastern University. She lives in the Bay Area with her family. 

 APPENDIX 1 – LEADERSHIP BIOS Jason P. Wells  38  Jason P. WellsSenior Vice President and Chief Financial OfficerPG&E Corporation Jason P. Wells is Senior Vice President and Chief Financial Officer for PG&E Corporation. Wells oversees the financial activities of the $50 billion company including accounting, treasury, tax, risk, business and financial planning, and investor relations.Wells began his career at PricewaterhouseCoopers, LLC, where he was most recently a senior manager. In 2007, Wells joined PG&E as the Director of technical accounting and was promoted to Senior Director and Assistant Controller of corporate accounting in 2008. In 2011, Wells became Vice President, Finance. He assumed his current position on January 2016.He earned his bachelor's and master's degrees in accounting from the University of Florida. Wells is a Certified Public Accountant in the state of Florida. He currently serves as the Treasurer and on the board of Habitat for Humanity Greater San Francisco. 

 APPENDIX 1 – LEADERSHIP BIOS Patrick M. Hogan  39  Patrick M. HoganSenior Vice President of Electric Transmission and DistributionPacific Gas and Electric CompanyPatrick M. Hogan is Senior Vice President of Electric Transmission & Distribution at Pacific Gas and Electric Company.Hogan oversees PG&E's electric transmission and distribution system, which delivers safe and reliable energy to more than 16 million people throughout Northern and Central California.Prior to his promotion to Senior Vice President of Electric Transmission & Distribution in 2016, Hogan served as Vice President of Electric Strategy & Asset Management where he oversaw the company's electric transmission and distribution assets. Hogan also led the development and deployment of technology into PG&E's electric system.Before joining PG&E in 2013, Hogan held leadership and officer roles in transmission, distribution, operations, engineering and asset management at British Columbia Hydro, National Grid, and KeySpan.Hogan holds a bachelor's and master's degree in electrical engineering from Manhattan College and a master's degree in business administration from Hofstra University. 

 APPENDIX 1 – LEADERSHIP BIOS Jesus Soto Jr.  40  Jesus Soto Jr.Senior Vice President, Gas OperationsPacific Gas and Electric CompanyJesus Soto Jr. is the Senior Vice President of Gas Operations for Pacific Gas and Electric Company. He is responsible for overseeing and executing the day-to-day operations of the second largest natural gas system in the United States. PG&E's natural gas system provides safe, reliable, affordable and clean gas service to 16 million people in northern and central California.Soto is passionate about public and employee safety and PG&E's Gas Operations earned ISO 55000 and PAS 55001 international certifications for the company's enhancements in gas asset management. PG&E is the only North American utility to currently hold these third party certifications. Through his leadership, PG&E was the first utility to deploy a state-of-the-art leak detection technology that is 1,000 times more sensitive than conventional leak detection tools. Soto's commitment to safety has led to a significant reduction in the time it takes PG&E to respond to gas odor calls.Most recently, Soto served as Vice President of Operations Services for El Paso Corporation's Pipeline Group in Houston, TX. He led the technical services and support functions for pipeline operations and oversaw measurement, compression, reservoir and pipeline systems and Department of Transportation compliance. He was also responsible for risk and integrity management, public awareness and emergency response. Prior to that, Soto was vice president of engineering and construction, leading the engineering and construction programs for ANR Pipeline, El Paso Natural Gas, Colorado Interstate Gas, Southern Natural Gas and Tennessee Gas Pipeline for onshore and offshore facilities.Soto holds a Bachelor of Science in civil engineering from the University of Texas at El Paso, a master's degree in civil engineering from Texas A&M University, and a Master of Business Administration degree from the University of Phoenix. 

 APPENDIX 1 – LEADERSHIP BIOS Steven E. Malnight  41  Steven (Steve) E. MalnightSenior Vice President, Regulatory Affairs Pacific Gas and Electric CompanySteve Malnight is Senior Vice President, Regulatory Affairs, for Pacific Gas and Electric Company. He is responsible for developing, coordinating and managing policy with state and federal regulatory agencies, including the California Public Utilities Commission (CPUC), the California Energy Commission (CEC) and the Federal Energy Regulatory Commission (FERC). He also is responsible for developing and filing rate proposals with the CPUC, and for oversight of the company’s gas and electric tariffs. Malnight joined PG&E in 2002 and has held diverse leadership positions within the company. After serving as Director of Customer Strategy and then Senior Director of Finance, leading the company’s budgeting and planning process, he became Special Assistant to the Chairman of PG&E’s Corporation in 2007. Subsequent roles included Vice President of Renewable Energy and Vice President of Customer Energy Solutions, an organization providing integrated energy solutions to help customers save energy and money. He was appointed Senior Vice President, Regulatory Affairs in September 2014.Malnight holds a Bachelor of Science degree in chemical engineering from the University of Notre Dame and an MBA from the Tuck School of Business at Dartmouth. He serves as Chairman of the Board of the Solar Electric Power Association, a nationwide organization that supports utility participation in solar activities. Malnight also serves on the Board of Advisors for The Salvation Army of Alameda County, a non-profit organization committed to serving families in crisis. 

 APPENDIX 1 – LEADERSHIP BIOS Nicholas M. Bijur  42  Nicholas M.BijurVice President and Treasurer PG&E CorporationPacific Gas and Electric CompanyNicholas M. Bijur is the Vice President and Treasurer of PG&E Corporation and Pacific Gas and Electric Company. He manages the Corporate Banking, Cash Management, and Investments and Benefit Finance organizations.Bijur has over ten years of finance experience. Prior to joining PG&E Corporation in 2005 as Assistant Treasurer, Bijur worked at Morgan Stanley in the Investment Banking division where he most recently served as a Vice President.Bijur received his bachelor's degree from Bucknell University and his MBA from the UCLA Anderson School of Management. 

 APPENDIX 1 – LEADERSHIP BIOS Janet C. Loduca  43  Janet C. LoducaVice President, Investor RelationsPG&E CorporationJanet Loduca is Vice President of Investor Relations at PG&E Corporation. She is responsible for providing the investment community with information about the Corporation and its operational and financial performance.Loduca joined Pacific Gas and Electric Company in 2000 and has held a number of positions including, most recently, Vice President of Safety, Health and Environment, where she led employee and contractor safety programs and oversaw the company's land and environmental programs and policies. Prior to this role, Loduca served as Vice President, Corporate Relations, where she was responsible for the company's internal and external communications, and chief of staff to PG&E’s president. She also held positions in the Regulatory Affairs organization and Law department.Prior to joining PG&E, Loduca was an environmental attorney in private practice and an environmental prosecutor with the U.S. Department of Justice. Loduca holds a bachelor's degree in political science from the University of Washington and a law degree from the University of San Francisco. She also serves on the board of directors for Girls Inc. of Alameda. 

 APPENDIX 1 – LEADERSHIP BIOS David S. Thomason  44  David S. ThomasonVice President and ControllerPG&E CorporationVice President, Chief Financial Officer and ControllerPacific Gas and Electric CompanyDavid S. Thomason is Vice President and Controller of PG&E Corporation, as well as Vice President, Chief Financial Officer and Controller of Pacific Gas and Electric Company.Thomason joined PG&E in 2001 as a senior accounting analyst after starting his career with Arthur Andersen in Portland. During his 16 years at PG&E, he has held a multitude of roles, growing as a leader and gaining additional responsibilities with each new position. Functional areas he has overseen include external financial reporting, revenue forecasting, planning and analysis, corporate accounting and more.Thomason received a Master's degree in Business Administration from University of California, Berkeley, and a Bachelor's degree in Accounting from University of Oregon, Eugene. He holds registrations as a Certified Public Accountant in the states of California and Oregon. 

 45  All amounts presented in the table above are tax adjusted at PG&E Corporation’s tax rate of 40.75 percent except for fines, which are not tax deductible.“Earnings from operations” is a non-GAAP financial measure. See Use of Non-GAAP Financial Measures.“Items impacting comparability” represent items that management does not consider part of the normal course of operations and affect comparability of financial results between periods. See Use of Non-GAAP Financial Measures.“Pipeline related expenses” includes costs incurred to identify and remove encroachments from transmission pipeline rights-of-way. The pre-tax range of estimated costs is shown below. The offsetting tax impacts for the low and high EPS guidance range are $51 million and $33 million, respectively.“Legal and regulatory related expenses” includes costs incurred in connection with various enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory communications. The pre-tax range of estimated costs is shown below. The offsetting tax impacts for the low and high EPS guidance range are $16 million and $4 million, respectively.“Fines and penalties” includes estimated future fines and penalties resulting from various enforcement, regulatory, and litigation activities regarding natural gas matters and regulatory communications. Guidance is consistent with the estimated 2017 components of the $1.6 billion San Bruno Penalty Decision in the gas transmission pipeline investigations. Guidance does not include amounts for other potential future fines and penalties, including probable disallowances that will be imposed by the CPUC in its phase two decision of the 2015 GT&S rate case for prohibited ex parte communications. The pre-tax range of estimated costs is shown below. The offsetting tax impact for the low and high EPS guidance range is $12 million.  APPENDIX 2 – 2017 SUPPLEMENTAL EARNINGS MATERIALSPG&E Corporation’s 2017 Earnings per Share Guidance 

 APPENDIX 2 – 2017 SUPPLEMENTAL EARNINGS MATERIALSPG&E Corporation’s 2017 Earnings per Share Guidance   46  “Butte fire related costs, net of insurance” refers to estimated third-party claims and legal costs associated with the Butte fire, and any related insurance recovery. The Utility currently is unable to estimate the low and high end of the range for 2017.“GT&S revenue timing impact” refers to the revenues that are expected to be recorded in excess of the 2017 authorized revenue requirements after the CPUC issues a final phase two decision in the 2015 GT&S rate case to address the allocation of the $850 million disallowance for safety-related work adopted in the San Bruno Penalty Decision. Due to the uncertainty regarding the revenue requirement the CPUC will ultimately adopt in the final phase two decision, the Utility will not be able to record a true-up of revenues under-collected since January 1, 2015 until after the final phase two decision is issued. In addition, accounting rules allow the Utility to recognize revenues in a given year only if they will be collected from customers within 24 months of the end of that year. Because the phase one decision directs the Utility to collect the difference between the adopted “interim” revenue requirements and the amounts previously collected in rates, retroactive to January 1, 2015, over a 36-month period, the Utility will complete recording the full true-up of under-collected revenues in 2017. The pre-tax range of estimated revenues is shown below. The offsetting tax impact for the low and high EPS guidance range is $65 million.Actual financial results for 2017 may differ materially from the guidance provided. For a discussion of the factors that may affect future results, see the Forward-Looking Statements. 

 APPENDIX 2 – 2017 SUPPLEMENTAL EARNINGS MATERIALS2017 General Earnings Sensitivities  47  PG&E Corporation and Pacific Gas and Electric Company  These general earnings sensitivities on factors that may affect 2017 earnings are forward-looking statements that are based on various assumptions. Actual results may differ materially. For a discussion of the factors that may affect future results, see the Forward-Looking Statements. 

 APPENDIX 2 – 2017 SUPPLEMENTAL EARNINGS MATERIALSUse of Non-GAAP Financial Measures  48  PG&E Corporation and Pacific Gas and Electric Company  PG&E Corporation discloses historical financial results and provides guidance based on “earnings from operations” in order to provide a measure that allows investors to compare the underlying financial performance of the business from one period to another, exclusive of items impacting comparability. “Earnings from operations” is a non-GAAP financial measure and is calculated as income available for common shareholders less items impacting comparability. “Items impacting comparability” represent items that management does not consider part of the normal course of operations and affect comparability of financial results between periods, including certain pipeline related expenses, certain legal and regulatory related expenses, fines and penalties, Butte fire related costs, impacts of the 2015 GT&S rate case, and insurance recoveries for natural gas matters. PG&E Corporation uses earnings from operations to understand and compare operating results across reporting periods for various purposes including internal budgeting and forecasting, short- and long-term operating planning, and employee incentive compensation. PG&E Corporation believes that earnings from operations provide additional insight into the underlying trends of the business allowing for a better comparison against historical results and expectations for future performance. Earnings from operations are not a substitute or alternative for GAAP measures such as consolidated income available for common shareholders and may not be comparable to similarly titled measures used by other companies.  

     49  Key Next Steps  Phase 2 final decision anticipatedin Q4 2016  Final decision anticipated in Q1 2017  FERC Settlement Conferences  General Rate Case  Gas Transmissionand Storage Case  Transmission Owner Case  Regulatory Jurisdiction  Time Period of Current Rate Case  Current Revenue Requirement Request  ROE  CPUC  2015-2017  $1.3B  10.4%  CPUC  2017-2019  $8.4B  10.4%  FERC  2017  $1.5B   10.9%*  *FERC TO cases have typically been settled blackbox without an explicit ROE; PG&E’s objective is to earn the CPUC authorized 10.4% ROE across the enterprise  

 Q4  Q3  Q2  Q1  APPENDIX 3 – OVERVIEW OF KEY REGULATORY CASES2017 CPUC General Rate Case  September 1, 2015 – Filed CPUC application requesting 2017 - 2019 revenuesAugust 3, 2016 – Filed all-party settlement agreement     Hearings delayed due to settlement discussions  Settlement filed August 3Workshop August 30   2017   Proposed decision JanuaryFinal decision February  50  Revenue Requirement ($ millions)   Utility’s GRCApplication  Settlement Agreement Increase/(Decrease)  Difference(Decrease)  2017  $ 319  $ 88  ($ 231)  2018  $ 467  $ 444  ($ 23)  2019  $ 368  $ 361  ($ 7)  2020  N/A  $ 361  N/A  Only two contested issues remain: A third post-test year in 2020 with an additional increase of $361 millionGas Leak Abatement cost recovery mechanism given pending Leak Abatement OIRAssigned Commissioner: PickerAdministrative Law Judge: Roscow   2016  

 APPENDIX 3 – OVERVIEW OF KEY REGULATORY CASES2015 CPUC Gas Transmission and Storage Rate Case  December 19, 2013 – Filed CPUC application seeking 2015 - 2017 revenues June 23, 2016 – CPUC voted out a final Phase 1 decision with interim revenues through 2018November 1, 2016 – ALJ issued Phase 2 proposed decision  Phase 1 proposed decisionPhase 1 final decision  Q4  Q3  Q2  Phase 2 proposed decisionPotential Phase 2 final decision     51  Rate modeling workshop   Assigned Commissioner: PetermanAdministrative Law Judge: Dudney   2016   *Difference compares Utility Requested Revenue Requirement to Phase 2 PD Revenue Requirement 

 APPENDIX 3 – OVERVIEW OF KEY REGULATORY CASESFERC Transmission Owner Rate Case  July 29, 2015 – Filed TO17 with FERC requesting $1.5 billion revenue requirement in 2016, a $300 million increase over 2015September 30, 2015 – FERC accepted TO17 and rate changes suspended until March 1, 2016September 1, 2016 – Filed settlement agreement with $1.3 billion revenue requirement, a ~$130 million increase over 2015  TO17 (2016 Revenues)  52 

 APPENDIX 3 – OVERVIEW OF KEY REGULATORY CASESDistributed Resources  Distributed Resources Plans  Integrated Distributed Energy Resources  July 1, 2015 – Filed Distributed Resources Plan with the CPUC providing detailed, technical overviews of how to evaluate and optimally integrate new distributed energy resources such as solar panels, electric vehicles, energy storage, energy efficiency and demand responseJanuary 27, 2016 – CPUC issued ruling and scoping memorandum laying out three concurrent tracks through early 2017Track 1 is underway and focuses on enhanced distribution planning tools and methodologies, related demos, and data accessTrack 2 will address field demosTrack 3 will address additional policy issues such as grid modernization investments  Phase 1 through August 2016Scope elements include:Determine how DERs can meet system needs Deploy cost-effective IDERsAlign utility financial interests with public policy objectives through an incentive mechanism pilotFinal Decision expected in Q4 2016  53 

 APPENDIX 3 – OVERVIEW OF KEY REGULATORY CASESCPUC Cost of Capital  54    Capital Structure  Cost  Common Equity  52%  10.40%  Preferred Stock  1%  5.60%  Long-Term Debt  47%  5.52%  Weighted Average Cost of Capital    8.06%  Current cost of capital, originally approved in 2012, has been extended through 2017Trigger mechanism suspended through 2017Next cost of capital application expected to be filed in April 2017  Authorized Structureand Cost  Trigger MechanismMoody’s Baa Utility Index  PG&E Benchmark rate at 5.00% 

 APPENDIX 3 – OVERVIEW OF KEY REGULATORY CASESElectric Vehicle Infrastructure  February 9, 2015 – Filed CPUC applicationMarch 21, 2016 – Filed settlement agreement to deploy ~7,500 charging stations over three years, at a cost of $160 million ($132 capital, $28 expense) Q4 2016 – Potential proposed and final decisions Assigned Commissioner: PetermanAdministrative Law Judge: Farrar  Capital Investment ($ millions)  2016  2017  2018  2019  2020  Total  Electric Vehicle Infrastructure (Settlement)  $0  $21  $39  $54  $18  ~$132M  Cost to implement PG&E’s Electric Vehicle charging program:  55 

 APPENDIX 3 – OVERVIEW OF KEY REGULATORY CASESEnergy Storage  Energy Storage RFO  AB 2868  CPUC Storage Rulemaking (R.10-12-007) established 1,325 MW target for all IOUs (580 MW target for PG&E) by 2024 with up to 50% utility ownership of transmission and distribution projects; first projects expected to come on line in May 2017 December 1, 2016 – Second solicitation will be issued targeting 120 MWs:Transmission 65 MWDistribution 40 MWCustomer 15 MW  California Legislature passed AB 2868, which allows for an incremental 500 MW of storage, allocated equally across the three IOUs Legislation authorizes additional storage and allows for utility ownership  56 

 APPENDIX 3 – OVERVIEW OF KEY REGULATORY CASESResidential Rate/NEM Decisions  57  Residential Rate Design OIR Decision  NEM 2.0  The CPUC reviewed residential rate structure issued a decision in July 2015 which:Transition from 4 to 2 tiers by 2019; PG&E is currently at 3 tiers“Super-User Surcharge” added in 2017 for consumption at or above 400% of baselineNo fixed charges in near-term, but adopts a $10 minimum bill for non-CARE customersRequires the utilities to file TOU rate proposals by January 2018, with pilots in 2016  The CPUC largely left NEM 1.0 rates in place, although its decision requires NEM 2.0 customers to take service under one of PG&E’s current TOU rates and to pay non-bypassable charges and small interconnection feesCurrent NEM tariff ends on July 1, 2017 or earlier if NEM installations reach the 5% capThe CPUC may review NEM in 2019 

 APPENDIX 4Breakdown of 2015 Total Revenue Requirement  2015 Revenue Requirement ($ in M)  58  ~$9,300 M  ~$6,100 M  ~$2,200 M  ~$17,600 M 

 APPENDIX 5Description of Gas System Safety Recognition  59  ISO 55001  API 1173  ISO (International Organization for Standardization) 55001 enables the development of an effective asset management system so that an organization can achieve its objectives consistently and sustainably over time. ISO consists of members from the national standards bodies of 162 countries and has published more than 19,500 international standards.   API RP (American Petroleum Institute Recommended Practice) 1173 outlines specific best practices for safe and effective pipeline operations underpinned by a healthy safety culture. PG&E joined other gas pipeline organizations, along with the National Transportation Safety Board and the Pipeline and Hazardous Materials Safety Administration to help co-author the standard.  PAS 55  PAS (Publicly Available Specification) 55 is a rigorous specification for optimized management of physical assets with widespread recognition among utilities, transport, mining, process and manufacturing industries worldwide. PAS 55 was developed by the Institute for Asset Management and published by the British Standards Institution.   RC 14001  RC (Responsible Care) 14001 is the chemical industry standard issued through the American Chemistry Council (ACC) for process and product safety; community communications; security and safety, health, environmental (SHE) practices. A third party audit reviewed end-to-end safety processes at the company, ultimately approving PG&E as the first utility to secure the certification. 

 APPENDIX 6Credit Metrics and Ratings  60  PG&E Corporation        Senior Unsecured Debt  BBB+  Baa1  BBB  Short-term Debt  F2  P-2  A-2  Outlook  Positive  Positive  Positive    Fitch  Moody’s  S&P  Pacific Gas and Electric Company        Senior Unsecured Debt  A-  A3  BBB+  Short-term Debt  F2  P-2  A-2  Outlook  Positive  Positive  Positive