OVERVIEW

PG&E Corporation, incorporated in California in 1995, is a holding company whose primary purpose is to hold interests in energy-based businesses. PG&E Corporation conducts its business principally through Pacific Gas and Electric Company ("Utility"), a public utility operating in northern and central California. The Utility engages in the businesses of electricity and natural gas distribution; electricity generation, procurement, and transmission; and natural gas procurement, transportation, and storage. PG&E Corporation became the holding company of the Utility and its subsidiaries on January 1, 1997. Both PG&E Corporation and the Utility are headquartered in San Francisco, California.

The Utility served approximately 5.1 million electricity distribution customers and approximately 4.3 million natural gas distribution customers at June 30, 2008. The Utility had approximately $38.3 billion in assets at June 30, 2008 and generated revenues of approximately $7.3 billion in the six months ended June 30, 2008.

The Utility is regulated primarily by the California Public Utilities Commission ("CPUC") and the Federal Energy Regulatory Commission ("FERC"). The Utility generates revenues mainly through the sale and delivery of electricity and natural gas at rates set by the CPUC and the FERC. Rates are set to permit the Utility to recover its authorized "revenue requirements" from customers. Revenue requirements are designed to allow the Utility an opportunity to recover its reasonable costs of providing utility services, including a return of, and a fair rate of return on, its investment in utility facilities ("rate base"). Pending regulatory proceedings that could result in rate changes and affect the Utility's revenues are discussed in PG&E Corporation's and the Utility's combined Annual Report on Form 10-K for the year ended December 31, 2007, which, together with the information incorporated by reference into such report, is referred to in this quarterly report as the "2007 Annual Report." Significant developments that have occurred since the 2007 Annual Report was filed with the Securities and Exchange Commission ("SEC") are discussed in this Quarterly Report on Form 10-Q.

This is a combined quarterly report of PG&E Corporation and the Utility, and includes separate Condensed Consolidated Financial Statements for each of these two entities. PG&E Corporation's Condensed Consolidated Financial Statements include the accounts of PG&E Corporation, the Utility, and other wholly owned and controlled subsidiaries. The Utility's Condensed Consolidated Financial Statements include the accounts of the Utility and its wholly owned and controlled subsidiaries which the Utility is required to consolidate under applicable accounting standards and variable interest entities for which the Utility absorbs a majority of the risk of loss or gain. This combined Management's Discussion and Analysis of Financial Condition and Results of Operations ("MD&A") of PG&E Corporation and the Utility should be read in conjunction with the Condensed Consolidated Financial Statements and the Notes to the Condensed Consolidated Financial Statements included in this quarterly report, as well as the MD&A, Consolidated Financial Statements, and Notes to the Consolidated Financial Statements incorporated by reference in the 2007 Annual Report.

Summary of Changes in Earnings per Common Share and Net Income for the Three and Six Months Ended June 30, 2008

For the three months ended June 30, 2008, PG&E Corporation's diluted earnings per common share ("EPS") was $0.80 compared to $0.74 for the same period in 2007. For the six months ended June 30, 2008, PG&E Corporation's diluted EPS was $1.42 compared to $1.45 for the same period in 2007. PG&E Corporation's net income for the three months ended June 30, 2008 increased by approximately $24 million, or 9%, to $293 million, compared to $269 million for the same period in 2007. For the six months ended June 30, 2008, net income decreased by approximately $8 million, or 2%, to $517 million, compared to $525 million for the same period in 2007.

The increase in diluted EPS and net income for the three months ended June 30, 2008 compared to the same period in 2007 is primarily due to (1) the Utility's return on equity ("ROE") on higher authorized capital investments (representing a $23 million increase in net income as compared to the same period in the prior year), and (2) lower refueling expenses at the Diablo Canyon nuclear generating facilities ("Diablo Canyon") than the prior year due to the timing of the outage (resulting in a $21 million increase in net income). These increases to net income were partially offset by increased operating and maintenance expenses associated with the natural gas system (resulting in a $6 million decrease in net income as compared to the same period in the prior year).

The decrease in diluted EPS and net income for the six months ended June 30, 2008 compared to the same period in 2007 is primarily due to (1) higher storm and outage-related costs, largely due to severe winter weather that occurred in January 2008 (resulting in a $26 million decrease in net income as compared to the same period in the prior year), (2)

increased refueling expenses at Diablo Canyon as compared to the same period in the prior year resulting from an extended outage to replace the steam generators in one of the nuclear generating units (resulting in a $6 million decrease in net income), (3) increased operating and maintenance expenses associated with the natural gas system (resulting in a $10 million decrease in net income), and
(4) other increased expenses (resulting in a $16 million decrease in net income). Most of the decreases in net income was offset by the Utility's ROE on higher authorized capital investments (representing a $51 million increase in net income as compared to the same period in the prior year).

Key Factors Affecting Results of Operations and Financial Condition

PG&E Corporation's and the Utility's results of operations and financial condition depend primarily on whether the Utility is able to operate its business within authorized revenue requirements, timely recover its authorized costs, and earn its authorized rate of return. A number of factors have had, or are expected to have, a significant impact on PG&E Corporation's and the Utility's results of operations and financial condition, including:

· The Outcome of Regulatory Proceedings and the Impact of Ratemaking Mechanisms. The amount of the Utility's revenues and the amount of costs that the Utility is authorized to recover from customers are primarily determined through regulatory proceedings. Most of the Utility's revenue requirements are based on its costs of service, in proceedings such as the General Rate Case ("GRC") filed with the CPUC and transmission owner ("TO") rate cases filed with the FERC. On July 30, 2008, the Utility filed a new TO rate case requesting a retail revenue requirement of approximately $849 million and a rate increase, effective October 1, 2008, to recover the costs associated with significant electric transmission infrastructure expansion and replacement. From time to time, the Utility also files separate applications requesting the CPUC or the FERC to authorize additional revenue requirements for specific projects, such as new power plants, gas or electric transmission projects, and the advanced metering infrastructure. On May 15, 2008, the Utility requested that the CPUC approve additional funding to improve customer service and reliability beyond the level assumed in the last GRC. The Utility's revenues can also be affected by incentive ratemaking, such as the CPUC's customer energy efficiency shareholder incentive mechanism. The amount of incentives the Utility may receive and the amount of any reimbursement obligations the Utility may incur will depend on the level of energy efficiency savings actually achieved over the three-year program cycles (2006-2008 and 2009-2011). (See "Regulatory Matters" below.) Finally, the outcome of regulatory proceedings may also be affected by increases in the prices of natural gas and electricity as these costs are passed through to customers in the form of higher rates.

· Capital Structure and Return on Common Equity. On May 29, 2008, the CPUC adopted a new three-year cost of capital mechanism to replace the CPUC's annual cost of capital proceeding. The Utility's current authorized capital structure, including a 52% common equity component, will be maintained through 2010. The Utility's current authorized cost of capital, including a ROE of 11.35% on its electric and natural gas distribution and electric generation rate base, will be maintained through 2010, unless the annual automatic adjustment mechanism established by the CPUC is triggered. The Utility can apply for an adjustment to either the capital structure or cost of capital sooner based on extraordinary circumstances. (See "Regulatory Matters" below.) In September 2007, the FERC accepted the Utility's request to earn a ROE of 12% on its electric transmission rate base, as part of the annual TO rate case, effective March 1, 2008, subject to hearing and refund.

· The Ability of the Utility to Control Costs. The Utility's revenue requirements are primarily set based on forecasted operating expenses and capital expenditures. The Utility's revenue requirements are designed to allow the Utility to earn an ROE, as well as to recover depreciation, tax, and interest expense associated with authorized capital expenditures. Material differences in the amount or timing of forecasted and actual operating expenses and capital expenditures can materially affect the Utility's ability to earn its authorized rate of return and the amount of PG&E Corporation's net income available for shareholders. In particular, the Utility anticipates that it will incur higher expenses than originally forecasted in the GRC in connection with the operations and maintenance of its natural gas system and maintenance of aging infrastructure. The Utility intends to continue its efforts to identify and implement initiatives to achieve operational efficiencies to create future sustainable cost-savings and to offset increased spending related to the natural gas system and the increasing cost of materials. (See "Results of Operations - Operating and Maintenance" below.) When capital is placed in service at a higher rate than forecasted, the Utility incurs associated depreciation, property tax, and interest expense. The Utility does not recover an ROE on the higher level of capital expenditures until added to rate base in future rate cases. The Utility's financial condition and results of operations will be impacted by the amount of revenue requirements it is authorized to recover, the amount and timing of its capital expenditures, and whether the Utility is able to manage its operating costs and capital expenditures within authorized revenues.

· The Amount and Timing of Debt and Equity Financing Needs. The Utility's needs for additional financing during 2008 and future years will be affected by the amount and timing of capital expenditures, as well as by the amount and timing of interest payments related to the remaining disputed claims that were made by electricity suppliers in the Utility's proceeding under Chapter 11 of the U.S. Bankruptcy Code ("Disputed Claims"). (See Note 10 of the Notes to the Condensed Consolidated Financial Statements.) In addition, the Utility's financing needs will be affected by when certain pollution control bonds aggregating $454 million that the Utility repurchased during March and April 2008 can be resold. The Utility's financial condition and results of operations will be affected by the interest rates, timing, and terms and conditions of any such financings. The timing and amount of PG&E Corporation's future equity contributions to the Utility will affect the timing and amount of any PG&E Corporation equity issuances and/or debt issuances which, in turn, will affect PG&E Corporation's results of operations and financial condition. (See "Liquidity and Financial Resources" below.)

In addition to the key factors discussed above, PG&E Corporation's and the Utility's future results of operations and financial condition are subject to the risk factors discussed in the section entitled "Risk Factors" in the 2007 Annual Report and the section entitled "PART II Item 1A. Risk Factors" below.

FORWARD-LOOKING STATEMENTS

This combined quarterly report on Form 10-Q, including the MD&A, contains forward-looking statements that are necessarily subject to various risks and uncertainties. These statements are based on current estimates, expectations, and projections about future events and assumptions regarding these events and management's knowledge of facts as of the date of this report. These forward-looking statements relate to, among other matters, anticipated costs and savings associated with the Utility's efforts to identify and implement initiatives to achieve operational efficiencies and to create future sustainable cost-savings, estimated capital expenditures, estimated environmental remediation liabilities, estimated tax liabilities, the anticipated outcome of various regulatory and legal proceedings, future cash flows, and the level of future equity or debt issuances, and are also identified by words such as "assume," "expect," "intend," "plan," "project," "believe," "estimate," "predict," "anticipate," "aim," "may," "might," "should," "would," "could," "goal," "potential," and similar expressions. PG&E Corporation and the Utility are not able to predict all the factors that may affect future results. Some of the factors that could cause future results to differ materially from those expressed or implied by the forward-looking statements, or from historical results, include, but are not limited to:

· the Utility's ability to manage capital expenditures and operating expenses within authorized levels and recover such costs through rates in a timely manner;

· the outcome of regulatory proceedings, including pending and future ratemaking proceedings at the CPUC and the FERC;

· the adequacy and price of electricity and natural gas supplies, and the ability of the Utility to manage and respond to the volatility of the electricity and natural gas markets;

· the effect of weather, storms, earthquakes, fires, floods, disease, other natural disasters, explosions, accidents, mechanical breakdowns, acts of terrorism, and other events or hazards on the Utility's facilities and operations, its customers, and third parties on which the Utility relies;

· the potential impacts of climate change on the Utility's electricity and natural gas businesses;

· changes in customer demand for electricity and natural gas resulting from unanticipated population growth or decline, general economic and financial market conditions, changes in technology, including the development of alternative energy sources, or other reasons;

· operating performance of Diablo Canyon, the occurrence of unplanned outages at Diablo Canyon, or the temporary or permanent cessation of operations at Diablo Canyon;

· whether the Utility can maintain the cost savings it has recognized from operating efficiencies it has achieved and identify and successfully implement additional sustainable cost-saving measures;

· whether the Utility incurs substantial unanticipated expense to improve the safety and reliability of its electric and natural gas distribution systems;

· whether the Utility achieves the CPUC's energy efficiency targets and recognizes any incentives the Utility may earn in a timely manner;

· the impact of changes in federal or state laws, or their interpretation, on energy policy and the regulation of utilities and their holding companies;

· the impact of changing wholesale electric or gas market rules, including new rules of the California Independent System Operator ("CAISO") to restructure the California wholesale electricity market;

· how the CPUC administers the conditions imposed on PG&E Corporation when it became the Utility's holding company;

· the extent to which PG&E Corporation or the Utility incurs costs and liabilities in connection with litigation that are not recoverable through rates, from insurance, or from other third parties;

· the ability of PG&E Corporation and/or the Utility to access capital markets and other sources of credit in a timely manner on favorable terms;

· the impact of environmental laws and regulations and the costs of compliance and remediation;

· the effect of municipalization, direct access, community choice aggregation, or other forms of bypass; and

· the impact of changes in federal or state tax laws, policies, or regulations.

For more information about the significant risks that could affect the outcome of these forward-looking statements and PG&E Corporation's and the Utility's future financial condition and results of operations, see the discussion in the section entitled "Risk Factors" in the 2007 Annual Report and the section entitled "Part II Item 1A. Risk Factors" below. PG&E Corporation and the Utility do not undertake an obligation to update forward-looking statements, whether in response to new information, future events or otherwise.

RESULTS OF OPERATIONS

        The table below details certain items from the accompanying Condensed
Consolidated Statements of Income for the three and six months ended June 30,
2008 and 2007:

                                              Three Months Ended             Six Months Ended
                                                   June 30,                      June 30,
(in millions)                                 2008           2007           2008           2007
Utility
Electric operating revenues                $    2,645      $   2,359     $    5,159      $   4,534
Natural gas operating revenues                    933            828          2,152          2,009
  Total operating revenues                      3,578          3,187          7,311          6,543
Cost of electricity                             1,097            884          2,124          1,607
Cost of natural gas                               487            396          1,262          1,150
Operating and maintenance                         991            921          2,027          1,840
Depreciation, amortization, and
decommissioning                                   418            430            820            859
  Total operating expenses                      2,993          2,631          6,233          5,456
Operating income                                  585            556          1,078          1,087
Interest income                                    33             35             57             83
Interest expense                                 (178 )         (178 )         (358 )         (360 )
Other income, net(1)                                3             11             19             17
Income before income taxes                        443            424            796            827
Income tax provision                              134            154            254            299
Income available for common stock          $      309      $     270     $      542      $     528
PG&E Corporation, Eliminations and
Other(2)
Operating revenues                         $        -      $       -     $        -      $       -
Operating expenses                                  1              1              1              3
Operating loss                                     (1 )           (1 )           (1 )           (3 )
Interest income                                     -              2              2              6
Interest expense                                   (7 )           (7 )          (14 )          (15 )
Other expense, net                                 (2 )           (1 )          (16 )           (3 )
Loss before income taxes                          (10 )           (7 )          (29 )          (15 )
Income tax provision (benefit)                      6             (6 )           (4 )          (12 )
Net loss                                   $      (16 )    $      (1 )   $      (25 )    $      (3 )
Consolidated Total
Operating revenues                         $    3,578      $   3,187     $    7,311      $   6,543
Operating expenses                              2,994          2,632          6,234          5,459
Operating income                                  584            555          1,077          1,084
Interest income                                    33             37             59             89
Interest expense                                 (185 )         (185 )         (372 )         (375 )
Other income, net(1)                                1             10              3             14
Income before income taxes                        433            417            767            812
Income tax provision                              140            148            250            287
Net income                                 $      293      $     269     $      517      $     525

(1) Includes preferred stock dividend requirement as other expense.
(2) PG&E Corporation eliminates all intercompany transactions in consolidation.

Utility

The following presents the Utility's operating results for the three and six months ended June 30, 2008 and 2007.

Electric Operating Revenues

The Utility provides electricity to residential, industrial, and small and large commercial customers through its own generation facilities and through contracts with third parties under power purchase agreements. In addition, the Utility relies on electricity provided under long-term contracts entered into by the California Department of Water Resources ("DWR") to meet a material portion of the Utility's customers' demand ("load"). The Utility's electric operating revenues consist of amounts charged to customers for electricity generation and procurement and for electric transmission and distribution services, as well as amounts charged to customers to recover the cost of public purpose programs, energy efficiency programs, and demand side management.

The following table provides a summary of the Utility's electric operating revenues:

                                                     Three Months Ended                        Six Months Ended
                                                          June 30,                                 June 30,
(in millions)                                     2008                 2007                2008                2007
Electric revenues                            $        2,948         $     2,868         $     5,789         $     5,594
DWR pass-through revenues(1)                           (303 )              (509 )              (630 )            (1,060 )
Total electric operating revenues            $        2,645         $     2,359         $     5,159         $     4,534
Total electricity sales (in Gigawatt
hours)(2)                                            18,141              16,177              35,477              30,955

(1)These are revenues collected on behalf of the DWR for electricity allocated to the Utility's customers under contracts between the DWR and power suppliers, and are not included in the Utility's Condensed Consolidated Statements of Income.
(2)These volumes exclude electricity provided by DWR.

The Utility's electric operating revenues increased by approximately $286 million, or 12%, in the three months ended June 30, 2008 and approximately $625 million, or 14%, in the six months ended June 30, 2008, compared to the same periods in 2007 mainly due to the following factors:

· Electricity procurement costs, which are passed through to customers, increased by approximately $208 million in the three months ended June 30, 2008 and approximately $505 million in the six months ended June 30, 2008, primarily due to an increase in the volume of power purchased by the Utility following the DWR's termination of a power purchase contract in December 2007 and during the scheduled outage at Diablo Canyon, and increases in purchased power prices. (See "Cost of Electricity" below.)

· Electric operating revenues to fund public purpose and energy efficiency programs increased by approximately $62 million in the three months ended June 30, 2008 and approximately $138 million in the six months ended June 30, 2008. (See "Operating and Maintenance" below.)

· Base revenue requirements increased by approximately $26 million in the three months ended June 30, 2008 and approximately $51 million in the six months ended June 30, 2008, as a result of attrition adjustments as authorized in the 2007 GRC.

· Electric transmission revenues increased by approximately $12 million in the three months ended June 30, 2008 and approximately $27 million in the six months ended June 30, 2008, primarily due to an increase in rates as authorized in the current TO rate case.

· Other electric operating revenues, including revenues to recover costs related to the Diablo Canyon steam generator replacement project and revenues to fund the Smart MeterTM advanced metering project, increased by approximately $43 million in the three months ended June 30, 2008 and approximately $39 million in the six months ended June 30, 2008. (See "Capital Expenditures" below.)

These increases were partially offset by a decrease of approximately $65 million in the three months ended June 30, 2008 and approximately $135 million in the six months ended June 30, 2008, representing the amount of revenue collected

during these periods for payment of principal and interest on the Rate Reduction Bonds ("RRBs") that matured in December 2007.

The Utility's electric operating revenues for 2009 and 2010 are expected to increase, as authorized by the CPUC in the 2007 GRC. The Utility's electric operating revenues for future years are also expected to increase as authorized by the FERC in the TO rate cases. In addition, the Utility expects to continue to collect revenue requirements related to CPUC-approved capital expenditures outside the GRC, including the new Utility-owned generation projects and the SmartMeterTM advanced metering project. Revenues would also increase to the extent the CPUC approves the Utility's proposal for other capital projects. (See "Capital Expenditures" below.) Revenue requirements associated with new or expanded public purpose, energy efficiency, and demand response programs will also result in increased electric operating revenues. Finally, future electric operating revenues will increase as the Utility's electricity procurement costs increase, as discussed under "Cost of Electricity" below.

Cost of Electricity

The Utility's cost of electricity includes electricity purchase costs and the cost of fuel used by its generation facilities or supplied to other facilities under tolling agreements. The Utility's cost of purchased power and the cost of fuel used in Utility-owned generation are passed through to customers. The . . .