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Document and Entity Information - shares	6 Months Ended
Document and Entity Information - shares	Jun. 30, 2011	Jul. 29, 2011
Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2011
Document Fiscal Year Focus	2011
Document Fiscal Period Focus	Q2
Trading Symbol	POR
Entity Registrant Name	PORTLAND GENERAL ELECTRIC CO /OR/
Entity Central Index Key	0000784977
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		75,341,327

Condensed Consolidated Statements of Income (Unaudited) - USD ($) shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2011	Jun. 30, 2010	Jun. 30, 2011	Jun. 30, 2010
Revenues, net	$ 411	$ 415	$ 895	$ 864
Operating expenses:
Purchased power and fuel	169	186	363	410
Production and distribution	55	46	97	85
Administrative and other	51	48	103	93
Depreciation and amortization	55	57	111	114
Taxes other than income taxes	24	21	49	44
Total operating expenses	354	358	723	746
Income from operations	57	57	172	118
Other income (expense):
Allowance for equity funds used during construction	1	4	2	8
Miscellaneous income (expense), net	1	(3)	3	(2)
Other income, net	2	1	5	6
Interest expense	28	26	55	55
Income before income taxes	31	32	122	69
Income taxes	9	8	31	18
Net income and Net income attributable to Portland General Electric Company	$ 22	$ 24	$ 91	$ 51
Weighted-average shares outstanding (in thousands):
Basic	75,326	75,276	75,322	75,253
Diluted	75,401	75,290	75,369	75,268
Earnings per share:
Basic	$ 0.29	$ 0.32	$ 1.21	$ 0.68
Diluted	0.29	0.32	1.21	0.68
Dividends declared per common share	$ 0.265	$ 0.26	$ 0.525	$ 0.515

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Jun. 30, 2011	Dec. 31, 2010
Current assets:
Cash and cash equivalents	$ 72	$ 4
Accounts receivable, net	134	137
Unbilled revenues	68	93
Inventories	61	56
Margin deposits	68	83
Regulatory assets - current	184	221
Other current assets	64	67
Total current assets	651	661
Electric utility plant, net	4,227	4,133
Regulatory assets - noncurrent	481	544
Non-qualified benefit plan trust	42	44
Nuclear decommissioning trust	36	34
Other noncurrent assets	66	75
Total assets	5,503	5,491
Current liabilities
Accounts payable and accrued liabilites	167	169
Liabilities from price risk mangement activities - current	163	188
Short-term debt	0	19
Current portion of long-term debt	0	10
Regulatory liabilities - current	19	25
Other current liabilities	74	78
Total current liabilities	423	489
Long-term debt, net of current portion	1,798	1,798
Regulatory liabilities - noncurrent	692	657
Deferred income taxes	483	445
Liabilities from price risk mangement activities - noncurrent	143	188
Unfunded status of pension and postretirement plans	115	140
Non-qualified benefit plan liabilities	98	97
Other noncurrent liabilities	103	78
Total liabilities	3,855	3,892
Commitments and contingencies (see notes)
Portland General Electric Company shareholders' equity:
Preferred stock, no par value, 30,000,000 shares authorized; none issued and outstanding as of June 30, 2011 and December 31, 2010	0	0
Common stock, no par value, 160,000,000 shares authorized; 75,341,104 and 75,316,419 shares issued and outstanding as of June 30, 2011 and December 31, 2010, respectively	832	831
Accumulated other comprehensive loss	(5)	(5)
Retained earnings	818	766
Total Portland General Electric Company shareholders' equity	1,645	1,592
Noncontrolling interests' equity	3	7
Total equity	1,648	1,599
Total liabilities and equity	$ 5,503	$ 5,491

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - $ / shares	Jun. 30, 2011	Dec. 31, 2010
Preferred stock, no par value	$ 0.00	$ 0.00
Preferred stock, shares authorized	30,000,000	30,000,000
Preferred stock, issued	0	0
Preferred stock, outstanding	0	0
Common stock, no par value	$ 0.00	$ 0.00
Common stock, shares authorized	160,000,000	160,000,000
Common stock, shares issued	75,341,104	75,316,419
Common stock, shares outstanding	75,341,104	75,316,419

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2011	Jun. 30, 2010
Cash flows from operating activities:
Net income	$ 91	$ 51
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	111	114
(Decrease) increase in net liabilities from price risk management activities	(64)	95
Regulatory deferral - price risk management activities	64	(95)
Deferred income taxes	33	18
Regulatory deferral of settled derivative instruments	12	27
Power cost deferrals, net	12	(1)
Renewable adjustment clause deferrals	11	7
Senate Bill 408 deferrals, net	(4)	(7)
Allowance for equity funds used during construction	(2)	(8)
Decoupling mechanism deferrals, net	0	(8)
Other non-cash income and expenses, net	15	19
Changes in working capital:
Decrease in receivables	28	59
Decrease (increase) in margin deposits, net	16	(21)
Income tax refund received	8	53
Decrease in payables	(16)	(37)
Other working capital items, net	(5)	(9)
Contribution to pension plan	(26)	0
Other, net	(5)	(11)
Net cash provided by operating activities	279	246
Cash flows from investing activities:
Capital expenditures	(138)	(264)
Sales of Nuclear decommissioning trust securities	29	18
Purchases of Nuclear decommissioning trust securities	(31)	(17)
Distribution from Nuclear decommissioning trust	0	19
Other, net	1	(1)
Net cash used in investing activities	(139)	(245)
Cash flows from financing activities:
Proceeds from issuance of long-term debt	0	249
Payments on long-term debt	(10)	(186)
Borrowings on short-term debt	0	8
Payments on commercial paper, net	(19)	0
Dividends paid	(39)	(38)
Debt issuance costs	0	(2)
Noncontrolling interests’ capital distributions	(4)	0
Net cash (used in) provided by financing activities	(72)	31
Increase in cash and cash equivalents	68	32
Cash and cash equivalents, beginning of period	4	31
Cash and cash equivalents, end of period	72	63
Supplemental cash flow information is as follows:
Cash paid for interest, net of amounts capitalized	51	49
Cash paid for income taxes	3	0
Non-cash investing and financing activities:
Accrued capital additions	24	23
Accrued dividends payable	21	20
Preliminary engineering transferred to construction work in progress from Other noncurrent assets	$ 7	$ 0

Basis of Presentation (Notes)	6 Months Ended
Basis of Presentation (Notes)	Jun. 30, 2011
Basis of Presentation [Abstract]
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	BASIS OF PRESENTATION Nature of Business Portland General Electric Company (PGE or the Company) is a single, vertically integrated electric utility engaged in the generation, purchase, transmission, distribution, and retail sale of electricity in the state of Oregon. The Company also sells electricity and natural gas in the wholesale market to utilities, brokers, and power and fuel marketers located in the United States and Canada. PGE operates as a single segment, with revenues and costs related to its business activities maintained and analyzed on a total electric operations basis. PGE’s corporate headquarters are located in Portland, Oregon and its service area is located within the state of Oregon. The Company served 824,526 retail customers as of June 30, 2011. Condensed Consolidated Financial Statements These condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). Certain information and footnote disclosures normally included in financial statements prepared in conformity with accounting principles generally accepted in the United States of America (GAAP) have been condensed or omitted pursuant to such regulations, although PGE believes that the disclosures provided are adequate to make the interim information presented not misleading. The financial information included herein for the three and six month periods ended June 30, 2011 and 2010 is unaudited; however, such information reflects all adjustments, consisting of normal recurring adjustments, that are, in the opinion of management, necessary for a fair presentation of the condensed consolidated financial position, condensed consolidated results of operations and condensed consolidated cash flows of the Company for these interim periods. Certain costs are estimated for the full year and allocated to interim periods based on estimates of operating time expired, benefit received, or activity associated with the interim period; accordingly, such costs may not be reflective of amounts to be recognized for a full year. Due to seasonal fluctuations in electricity sales, as well as the price of wholesale energy and natural gas, interim financial results do not necessarily represent those to be expected for the year. The financial information as of December 31, 2010 is derived from the Company’s audited consolidated financial statements and notes thereto for the year ended December 31, 2010, included in Item 8 of PGE’s Annual Report on Form 10-K, filed with the SEC on February 25, 2011, and should be read in conjunction with such consolidated financial statements. Use of Estimates The preparation of condensed consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, and disclosures of potential gain or loss contingencies, as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results experienced by the Company could differ materially from those estimates. Reclassifications PGE has separately presented regulatory deferrals related to the renewable adjustment clause from Other non-cash income and expenses, net in the Cash flows from operating activities section of the consolidated statement of cash flows for the six months ended June 30, 2010 to conform with the 2011 presentation. Recent Accounting Pronouncements Accounting Standards Update (ASU) 2010-06, Fair Value Measurements and Disclosures (Topic 820) - Improving Disclosures about Fair Value Measurements (ASU 2010-06) requires, among other matters, separate reporting about purchases, sales, issuances, and settlements for Level 3 fair value measurements. For additional information on Level 3, see Note 3, Fair Value of Financial Instruments. In accordance with the provisions of ASU 2010-06, PGE adopted this requirement of ASU 2010-06 on January 1, 2011, which did not have a material impact on the Company’s consolidated financial position, consolidated results of operations, or consolidated cash flows. All other requirements of ASU 2010-06 were adopted on January 1, 2010 in accordance with ASU 2010-06. In May 2011, ASU 2011-04, Fair Value Measurements and Disclosures (Topic 820) - Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRSs (ASU 2011-04) was issued. Many of the amendments in ASU 2011-04 change the wording used to describe principles and requirements to align with International Financial Reporting Standards as issued by the International Accounting Standards Board, and are not intended to change the application of Topic 820. Some of the amendments clarify the Financial Accounting Standards Board’s intent on the application of existing fair value guidance or change a particular principle or requirement for measuring fair value or fair value disclosures. The amendments in ASU 2011-04 are to be applied prospectively and are effective for interim and annual periods beginning after December 15, 2011 for public entities, with early application not permitted. PGE will adopt the amendments contained in ASU 2011-04 on January 1, 2012, which are not expected to have a material impact on the Company’s consolidated financial position, consolidated results of operations, or consolidated cash flows. In June 2011, ASU 2011-05, Comprehensive Income (Topic 220) - Presentation of Comprehensive Income (ASU 2011-05) was issued. The amendments of ASU 2011-05 require that an entity report items of other comprehensive income in one of two ways: (i) a single statement with components of net income and total net income, the components of comprehensive income and total other comprehensive income, and a total for comprehensive income; or (ii) two statements with components of net income and total net income in the first statement, immediately followed by a statement that presents the components of other comprehensive income, a total for other comprehensive income, and a total for comprehensive income. The amendments in ASU 2011-05 are to be applied retrospectively and are effective for interim and annual periods beginning after December 15, 2011, with early application permitted. PGE will adopt the amendments contained in ASU 2011-05 on January 1, 2012, which will not have a material impact on the Company’s consolidated financial position, consolidated results of operations, or consolidated cash flows.

- Definition

The entire disclosure for organization, consolidation and basis of presentation of financial statements disclosure.

+ References

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+ Details

Balance Sheet Components (Notes)

6 Months Ended

Jun. 30, 2011

Balance Sheet Components Note [Abstract]

BALANCE SHEET COMPONENTS

Accounts Receivable, Net

Accounts receivable is net of an allowance for uncollectible accounts of $5 million as of June 30, 2011 and December 31, 2010.

The activity in the allowance for uncollectible accounts is as follows (in millions):



	Six Months Ended June 30,
	2011			2010
Balance as of beginning of period	$	5		$	5
Provision, net	3			3
Amounts written off, less recoveries	(3		)	(3		)
Balance as of end of period	$	5		$	5

Inventories

Inventories consist primarily of materials, supplies, and fuel. Materials and supplies inventories are used in operations and maintenance and capital activities, and are recorded at average cost. Fuel inventories include natural gas, coal, and oil and are used in PGE’s generating plants. Natural gas is recorded at the lower of average cost or market, with coal and oil recorded at average cost.

Electric Utility Plant, Net

Electric utility plant, net consists of the following (in millions):



	June 30, 2011			December 31, 2010
Electric utility plant	$	6,458		$	6,279
Construction work in progress	121			125
Total cost	6,579			6,404
Less: accumulated depreciation and amortization	(2,352		)	(2,271		)
Electric utility plant, net	$	4,227		$	4,133

In 2011, $7 million of costs related to the Cascade Crossing Transmission Project were transferred to Construction work in progress. Such costs were previously included within preliminary engineering, which is included in Other noncurrent assets in the condensed consolidated balance sheets.

Accumulated depreciation and amortization in the table above includes accumulated amortization related to intangible assets of $143 million and $133 million as of June 30, 2011 and December 31, 2010, respectively. Amortization expense related to intangible assets was $5 million and $4 million for the three months ended June 30, 2011 and 2010, respectively, and $9 million and $7 million for the six months ended June 30, 2011 and 2010, respectively.

Regulatory Assets and Liabilities

Regulatory assets and liabilities consist of the following (in millions):



	June 30, 2011				December 31, 2010
	Current		Noncurrent		Current		Noncurrent
Regulatory assets:
Price risk management	$	153	$	142	$	175	$	185
Pension and other postretirement plans	—		207		—		213
Deferred income taxes	—		91		—		95
Deferred broker settlements	12		—		24		—
Renewable energy deferral	12		—		22		—
Debt reacquisition costs	—		22		—		23
Other	7		19		—		28
Total regulatory assets	$	184	$	481	$	221	$	544
Regulatory liabilities:
Asset retirement removal costs	$	—	$	612	$	—	$	588
Asset retirement obligations	—		34		—		33
Power cost adjustment mechanism	—		12		—		—
Regulatory treatment of income taxes (SB 408)	8		1		5		9
Trojan ISFSI pollution control tax credits	9		5		18		4
Other	2		28		2		23
Total regulatory liabilities	$	19	$	692	$	25	$	657

In May 2011, Oregon Senate Bill 967 (SB 967) was enacted, which repealed previously existing statutes (collectively referred to as ‘SB 408’) governing the annual adjustment of public utility rates to account for differences in taxes paid by electricity and natural gas utilities and amounts collected from customers for taxes. SB 967 is effective beginning with the annual filing pertaining to 2010. Accordingly, no annual SB 408 reports or corresponding price adjustments will be required for 2010 and subsequent years. The enactment of SB 967 did not have a material impact on PGE’s consolidated financial statements as minor amounts had been recorded related to SB 408 for 2011 or 2010 as of June 30, 2011 or December 31, 2010. With the enactment of SB 967, taxes paid by electricity and natural gas utilities will be considered in connection with general ratemaking proceedings.

Other Current Liabilities

Other current liabilities consist of the following (in millions):



	June 30, 2011		December 31, 2010
Accrued interest payable	$	26	$	26
Accrued taxes payable	19		22
Accrued dividends payable	21		20
Other	8		10
Total other current liabilities	$	74	$	78

Other Noncurrent Liabilities

During the first half of 2011, an updated decommissioning study for the Company’s Boardman coal-fired plant was completed, which assumed that Boardman’s coal-fired operations cease in 2020. As a result of the study, PGE increased its asset retirement obligation related to Boardman by approximately $23 million, with a corresponding increase in the cost basis of the plant, included in Electric utility plant, net on the condensed consolidated balance sheets.

Credit Facilities

PGE has the following unsecured revolving credit facilities:


•	A $370 million syndicated credit facility, with $10 million and $360 million scheduled to terminate in July 2012 and July 2013, respectively;


•	A $200 million syndicated credit facility, which is scheduled to terminate in December 2012; and


•	A $30 million credit facility, which is scheduled to terminate in June 2013.

Pursuant to the individual terms of the agreements, all credit facilities may be used for general corporate purposes and as backup for commercial paper borrowings. The $370 million and $30 million credit facilities also permit the issuance of standby letters of credit. All credit facilities contain customary covenants and default provisions, including a requirement that limits consolidated indebtedness, as defined in the agreements, to 65% of total capitalization. As of June 30, 2011, PGE was in compliance with this covenant with a 52.2% debt to total capital ratio.

The Company has a commercial paper program under which it may issue commercial paper for terms of up to 270 days, limited to the unused amount of credit under the credit facilities.

Pursuant to an order issued by the Federal Energy Regulatory Commission (FERC), the Company is authorized to issue short-term debt up to $750 million through February 6, 2012. The authorization contains a standard provision which provides that if utility assets financed by unsecured debt are divested, then a proportionate share of the unsecured debt must also be divested.

As of June 30, 2011, PGE had $126 million of letters of credit and no commercial paper or borrowings outstanding under the credit facilities. As of June 30, 2011, the aggregate unused credit available under the credit facilities was $474 million.

Pension and Other Postretirement Benefits

Components of net periodic benefit cost are as follows for the three months ended June 30 (in millions):



	Defined Benefit Pension Plan						Other Postretirement Benefit Plans				Non-Qualified Benefit Plans
	2011			2010			2011		2010		2011		2010
Service cost	$	3		$	3		$	—	$	—	$	—	$	—
Interest cost	7			7			1		1		—		—
Expected return on plan assets	(10		)	(10		)	—		—		—		—
Amortization of net actuarial gain	2			1			—		1		—		—
Net periodic benefit cost	$	2		$	1		$	1	$	2	$	—	$	—

Components of net periodic benefit cost are as follows for the six months ended June 30 (in millions):



	Defined Benefit Pension Plan						Other Postretirement Benefit Plans				Non-Qualified Benefit Plans
	2011			2010			2011		2010		2011		2010
Service cost	$	6		$	6		$	1	$	1	$	—	$	—
Interest cost	14			14			2		2		1		1
Expected return on plan assets	(20		)	(20		)	—		—		—		—
Amortization of net actuarial gain	4			2			—		1		—		—
Net periodic benefit cost	$	4		$	2		$	3	$	4	$	1	$	1

Fair Value of Financial Instruments (Notes)

6 Months Ended

Jun. 30, 2011

Fair Value of Financial Instruments Note [Abstract]

FAIR VALUE OF FINANCIAL INSTRUMENTS

The Company determines the fair value of financial instruments, both assets and liabilities recognized and not recognized in PGE’s condensed consolidated balance sheets, for which it is practicable to estimate fair value based on the following inputs as of June 30, 2011 and December 31, 2010:


•	Derivative instruments are recorded at fair value and are based on published market indices, which may be adjusted for market variables such as location pricing differences and/or the effects of liquidity at different locations. The Company also values certain derivative instruments using either standardized or internally developed models;


•	Certain trust assets, consisting of money market funds and fixed income securities included in the Nuclear decommissioning trust and marketable securities included in the Non-qualified benefit plan trust, are recorded at fair value and are based on quoted market prices; and

•

The fair value of long-term debt is estimated based on the quoted market prices for the same or similar issues or on the current rates offered to PGE for debt of similar remaining maturities. As of June 30, 2011, the estimated aggregate fair value of PGE’s long-term debt was $1,969 million, compared to its $1,798 million carrying amount. As of December 31, 2010, the estimated aggregate fair value of PGE’s long-term debt was $1,968 million, compared to its $1,808 million carrying amount.

A fair value hierarchy is used to prioritize the inputs to the valuation techniques used to measure fair value. The three broad levels and application to the Company are discussed below.

Level 1 — Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of financial instruments such as exchange-traded derivatives, listed equities and U.S. government treasury securities.

Level 2 — Pricing inputs are other than quoted market prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data, or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives, such as over-the-counter forwards and swaps, and debt securities other than U.S. Treasuries.

Level 3 — Pricing inputs include significant inputs that are generally less observable than objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. Level 3 instruments include those that may be more structured or otherwise tailored to customers’ needs. At each balance sheet date, the Company performs an analysis of all instruments subject to fair value measurement and includes in Level 3 all of those instruments whose fair value is based on significant unobservable inputs.

The Company’s financial assets and liabilities whose values were recognized at fair value are as follows by level within the fair value hierarchy (in millions):



	As of June 30, 2011
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trust ⁽¹⁾:
Money market funds	$	—	$	14	$	—	$	14
Debt securities:
U.S. treasury securities	8		—		—		8
Corporate debt securities	—		5		—		5
Mortgage-backed securities	—		6		—		6
Municipal securities	—		2		—		2
Asset-backed securities	—		1		—		1
Non-qualified benefit plan trust ⁽²⁾:
Equity securities:
Mutual funds	13		1		—		14
Common stocks	2		—		—		2
Debt securities - mutual funds	3		—		—		3
Assets from price risk management activities ^{(1) (3)}:
Electricity	—		6		1		7
Natural gas	—		3		—		3
	$	26	$	38	$	1	$	65
Liabilities - Liabilities from price risk management activities ^{(1) (3)}:
Electricity	$	—	$	68	$	25	$	93
Natural gas	—		110		103		213
	$	—	$	178	$	128	$	306


(1)	Activities are subject to regulation, with certain gains and losses deferred pursuant to regulatory accounting and included in Regulatory assets or Regulatory liabilities as appropriate.


(2)	Excludes insurance policies of $23 million, which are recorded at cash surrender value.


(3)	For further information, see Note 4, Price Risk Management.



	As of December 31, 2010
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trust ⁽¹⁾:
Money market funds	$	—	$	13	$	—	$	13
Debt securities:
U.S. treasury securities	3		—		—		3
Corporate debt securities	—		6		—		6
Mortgage-backed securities	—		7		—		7
Municipal securities	—		4		—		4
Asset-backed securities	—		1		—		1
Non-qualified benefit plan trust ⁽²⁾:
Equity securities:
Mutual funds	16		1		—		17
Common stocks	2		—		—		2
Debt securities - mutual funds	2		—		—		2
Assets from price risk management activities ^{(1) (3)}:
Electricity	—		4		1		5
Natural gas	—		11		—		11
	$	23	$	47	$	1	$	71
Liabilities - Liabilities from price risk management activities ^{(1) (3)}:
Electricity	$	—	$	102	$	17	$	119
Natural gas	—		153		104		257
	$	—	$	255	$	121	$	376


(1)	Activities are subject to regulation, with certain gains and losses deferred pursuant to regulatory accounting and included in Regulatory assets or Regulatory liabilities as appropriate.


(2)	Excludes insurance policies of $23 million, which are recorded at cash surrender value.


(3)	For further information, see Note 4, Price Risk Management.

Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

Nuclear decommissioning trust assets reflect the assets held in trust to fund general decommissioning costs and operation of the Independent Spent Fuel Storage Installation (ISFSI) and consist of money market funds and fixed income securities. Non-qualified benefit plan trust reflects the assets held in trust to fund a portion of the obligations of PGE’s non-qualified benefit plans and consist primarily of marketable securities.

Assets and liabilities from price risk management activities represent derivative transactions entered into by PGE to manage its exposure to commodity price risk and minimize net power costs for service to the Company’s retail customers and may consist of forward, swap, and option contracts for electricity, natural gas, oil, and foreign currency, and futures contracts for natural gas and oil. PGE applies a market-based approach to the fair value measurement of its derivative transactions. Inputs into the valuation of derivative activities include forward commodity and foreign exchange pricing, interest rates, volatility and correlation. PGE utilizes the Black-Scholes and Monte Carlo pricing models for commodity option contracts. Forward pricing, which employs the mid-point of the market’s bid-ask spread, is derived using observed transactions in active markets, as well as historical experience as a participant in those markets, and is validated against nonbinding quotes from brokers with whom the Company transacts. Interest rates used to calculate the present value of derivative valuations incorporate PGE’s borrowing ability. The Company also considers the liquidity of delivery points of executed transactions when determining where in the fair value hierarchy a transaction should be classified. PGE considers its creditworthiness and the creditworthiness of its counterparties when determining the appropriateness of a particular transaction’s assigned Level in the fair value hierarchy.

Changes in the fair value of net liabilities from price risk management activities (net of assets from price risk management activities) classified as Level 3 in the fair value hierarchy were as follows (in millions):



	Three Months		Six Months
	Ended June 30,		Ended June 30,
	2011		2011
Net liabilities from price risk management activities as of beginning of period	$	116	$	120
Realized and unrealized (gains) and losses, net	10		8
Purchases	1		—
Settlements	—		(1		)
Net liabilities from price risk management activities as of end of period	$	127	$	127

	Three Months		Six Months
	Ended June 30,		Ended June 30,
	2010		2010
Net liabilities from price risk management activities as of beginning of period	$	221	$	154
Realized and unrealized (gains) and losses, net	2		59
Purchases, issuances and settlements, net	2		12
Net liabilities from price risk management activities as of end of period	$	225	$	225

The Level 3 net realized and unrealized (gains) losses presented in the preceding table are recorded in Purchased power and fuel expense in the condensed consolidated statements of income and have been fully offset by the effects of regulatory accounting. Transfers into Level 3 occur when significant inputs used to value the Company’s derivative instruments become less observable, such as a delivery location becoming significantly less liquid. Transfers out of Level 3 occur when the significant inputs become more observable, such as the time between the valuation date and the delivery term of a transaction becomes shorter. PGE records transfers in and transfers out of Level 3 at the end of the reporting period for all of its financial instruments.

- Definition

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 44A, 44B
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15C, 15D
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15A
-Subparagraph a-d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15B
-Subparagraph a, b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 3, 10, 14, 15
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 157
-Paragraph 32, 33, 34
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 159
-Paragraph 17-22, 27, 28
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Reference 8: http://www.xbrl.org/2003/role/presentationRef
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+ Details

Price Risk Management (Notes)

6 Months Ended

Jun. 30, 2011

Price Risk Management Note [Abstract]

Derivative Instruments and Hedging Activities Disclosure [Text Block]

PRICE RISK MANAGEMENT

PGE participates in the wholesale marketplace in order to balance its supply of power, which consists of its own generating resources combined with wholesale market transactions, to meet the needs of its retail customers, manage risk, and administer its existing long-term wholesale contracts. Such activities include power purchases and sales resulting from economic dispatch decisions for Company-owned generation. As a result of this ongoing business activity, PGE is exposed to commodity price risk and foreign currency exchange rate risk, where adverse changes in prices and/or rates may affect the Company’s financial position, results of operations, or cash flow.

PGE utilizes derivative instruments in its wholesale electric utility activities to manage its exposure to commodity price risk and foreign currency exchange rate risk, mitigate the effects of market fluctuations, and minimize net power costs for service to its retail customers. These derivative instruments may include forward, swap, and option contracts for electricity, natural gas, oil, and foreign currency, and futures contracts for natural gas and oil. All derivative instruments are recorded at fair value on the balance sheet, with changes in fair value recorded in the statement of income. However, as a regulated entity, PGE recognizes a regulatory asset or liability in order to defer gains and losses from derivative activity until realized, in accordance with the ratemaking and cost recovery process authorized by the OPUC. This accounting treatment defers the mark-to-market gains and losses on derivative activities until settlement. PGE may designate certain derivative instruments as cash flow hedges or may use derivative instruments as purely economic hedges. PGE does not engage in trading activities for non-retail purposes.

PGE has elected to report gross on the balance sheet the positive and negative exposures resulting from derivative instruments entered into with counterparties where a master netting arrangement exists. As of June 30, 2011 and December 31, 2010, the Company had $17 million and $31 million, respectively, in collateral posted with these counterparties, consisting entirely of letters of credit.

PGE’s net volumes related to its Assets and Liabilities from price risk management activities resulting from its derivative transactions were as follows (in millions):



	June 30, 2011			December 31, 2010
Commodity contracts:
Electricity	12		MWh	9		MWh
Natural gas	82		Decatherms	93		Decatherms
Foreign currency	$	11	Canadian	$	7	Canadian

The fair value of PGE’s Assets and Liabilities from price risk management activities consists of the following (in millions):



	June 30, 2011			December 31, 2010
Current assets:
Commodity contracts:
Electricity	$	6		$	4
Natural gas	3			9
Total current derivative assets	9		⁽¹⁾	13		⁽¹⁾
Noncurrent assets:
Commodity contracts:
Electricity	1			1
Natural gas	—			2
Total noncurrent derivative assets	1		⁽²⁾	3		⁽²⁾
Total derivative assets not designated as hedging instruments	$	10		$	16
Total derivative assets	$	10		$	16
Current liabilities:
Commodity contracts:
Electricity	$	56		$	77
Natural gas	107			111
Total current derivative liabilities	163			188
Noncurrent liabilities:
Commodity contracts:
Electricity	37			42
Natural gas	106			146
Total noncurrent derivative liabilities	143			188
Total derivative liabilities not designated as hedging instruments	$	306		$	376
Total derivative liabilities	$	306		$	376


(1)	Included in Other current assets on the condensed consolidated balance sheets.


(2)	Included in Other noncurrent assets on the condensed consolidated balance sheets.

Net realized and unrealized gains (losses) on derivative transactions not designated as hedging instruments are classified in Purchased power and fuel, net of deferrals related to regulatory accounting, in the condensed consolidated statements of income and were as follows (in millions):



	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010
Commodity contracts:
Electricity	$	1		$	(6	)	$	(31	)	$	(59	)
Natural Gas	(17		)	(18		)	(11		)	(109		)

Unrealized gains and losses and certain realized gains and losses presented in the table above are offset within the statements of income by the effects of regulatory accounting. Of the net gain (loss) recognized in net income for the three months ended June 30, 2011 and 2010, net losses of $10 million and $25 million, respectively, have been offset, with $35 million and $159 million offset for the six months ended June 30, 2011 and 2010, respectively.

Assuming no changes in market prices and interest rates, the following table indicates the year in which the net unrealized loss recorded as of June 30, 2011 related to PGE’s derivative activities would become realized as a result of the settlement of the underlying derivative instrument (in millions):



	2011		2012		2013		2014		2015		Total
Commodity contracts:
Electricity	$	22	$	39	$	18	$	7	$	—	$	86
Natural gas	56		97		46		10		1		210
Net unrealized loss	$	78	$	136	$	64	$	17	$	1	$	296

The Company’s secured and unsecured debt is currently rated at investment grade by Moody’s Investors Service (Moody’s) and Standard and Poor’s Ratings Services (S&P). Should Moody’s and/or S&P reduce their rating on the Company’s unsecured debt to below investment grade, PGE could be subject to requests by certain wholesale counterparties to post additional performance assurance collateral, in the form of cash or letters of credit, based on total portfolio positions with each of those counterparties and certain other counterparties would have the right to terminate their agreements with the Company.

The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position as of June 30, 2011 was $255 million, for which the Company has $106 million in posted collateral, consisting entirely of letters of credit. If the credit-risk-related contingent features underlying these agreements were triggered at June 30, 2011, the cash requirement to either post as collateral or settle the instruments immediately would have been $249 million.

Counterparties representing 10% or more of Assets and Liabilities from price risk management activities as of June 30, 2011 or December 31, 2010 were as follows:



	June 30, 2011		December 31, 2010
Assets from price risk management activities:
Counterparty A	24	%	22	%
Counterparty B	13		11
Counterparty C	12		23
Counterparty D	10		1
Counterparty E	—		10
	59	%	67	%
Liabilities from price risk management activities:
Counterparty C	25	%	24	%
Counterparty F	10		9
Counterparty G	9		12
	44	%	45	%

See Note 3 for additional information concerning the determination of fair value for the Company’s Assets and Liabilities from price risk management activities.

- Definition

The entire disclosure for the entity's entire derivative instruments and hedging activities. Describes an entity's risk management strategies, derivatives in hedging activities and non-hedging derivative instruments, the assets, obligations, liabilities, revenues and expenses arising therefrom, and the amounts of and methodologies and assumptions used in determining the amounts of such items.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 45
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 44
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 50
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+ Details

Earnings Per Share (Notes)

6 Months Ended

Jun. 30, 2011

Earnings Per Share [Abstract]

EARNINGS PER SHARE

Components of basic and diluted earnings per share were as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2011		2010		2011		2010
Numerator (in millions):
Net income attributable to Portland General Electric Company common shareholders	$	22	$	24	$	91	$	51
Denominator (in thousands):
Weighted-average common shares outstanding - basic	75,326		75,276		75,322		75,253
Dilutive effect of unvested restricted stock units and employee stock purchase plan shares	75		14		47		15
Weighted-average common shares outstanding - diluted	75,401		75,290		75,369		75,268
Earnings per share:
Basic	$	0.29	$	0.32	$	1.21	$	0.68
Diluted	$	0.29	$	0.32	$	1.21	$	0.68

Unvested performance stock units and related dividend equivalent rights are not included in the computation of dilutive securities because vesting of these instruments is dependent upon three-year performance periods and the vesting criteria have not been met as of the end of the reporting period presented.

Basic and diluted earnings per share amounts are calculated based on actual amounts rather than the rounded amounts presented in the table above and on the condensed consolidated statements of income. Accordingly, calculations using the rounded amounts presented for net income and weighted average shares outstanding may yield results that vary from the earnings per share amounts presented in the table above.

Equity (Notes)

6 Months Ended

Jun. 30, 2011

Stockholders' Equity Note [Abstract]

Stockholders' Equity Note Disclosure [Text Block]

EQUITY

The activity in equity during the six months ended June 30, 2011 and 2010 is as follows (dollars in millions):



	Portland General Electric Company Shareholders’ Equity
	Common Stock			Accumulated Other Comprehensive Loss			Retained Earnings			Noncontrolling Interests’ Equity
	Shares	Amount		Accumulated Other Comprehensive Loss			Retained Earnings			Noncontrolling Interests’ Equity
Balances as of December 31, 2010	75,316,419	$	831	$	(5	)	$	766		$	7
Vesting of restricted stock units	12,104	—		—			—			—
Issuance of shares pursuant to employee stock purchase plan	11,320	—		—			—			—
Issuance of shares pursuant to dividend reinvestment and direct stock purchase plan	1,261	—		—			—			—
Stock-based compensation	—	1		—			—			—
Dividends declared	—	—		—			(39		)	—
Capital distribution	—	—		—			—			(4		)
Net income	—	—		—			91			—
Balances as of June 30, 2011	75,341,104	$	832	$	(5	)	$	818		$	3

Balances as of December 31, 2009	75,210,580	$	829	$	(6	)	$	719		$	1
Vesting of restricted and performance stock units	69,561	—		—			—			—
Issuance of shares pursuant to employee stock purchase plan	14,846	—		—			—			—
Stock-based compensation	—	1		—			—			—
Dividends declared	—	—		—			(39		)	—
Net income	—	—		—			51			—
Other comprehensive income	—	—		1			—			—
Balances as of June 30, 2010	75,294,987	$	830	$	(5	)	$	731		$	1

Effective April 1, 2011, PGE implemented a Dividend Reinvestment and Direct Stock Purchase Plan, under which the Company may issue up to 2,500,000 shares of common stock.

- Definition

The entire disclosure for shareholders' equity, comprised of portions attributable to the parent entity and noncontrolling interest, if any, including other comprehensive income (as applicable). Including, but not limited to: (1) balances of common stock, preferred stock, additional paid-in capital, other capital and retained earnings; (2) accumulated balance for each classification of other comprehensive income and total amount of comprehensive income; (3) amount and nature of changes in separate accounts, including the number of shares authorized and outstanding, number of shares issued upon exercise and conversion, and for other comprehensive income, the adjustments for reclassifications to net income; (4) rights and privileges of each class of stock authorized; (5) basis of treasury stock, if other than cost, and amounts paid and accounting treatment for treasury stock purchased significantly in excess of market; (6) dividends paid or payable per share and in the aggregate for each class of stock for each period presented; (7) dividend restrictions and accumulated preferred dividends in arrears (in aggregate and per share amount); (8) retained earnings appropriations or restrictions, such as dividend restrictions; (9) impact of change in accounting principle, initial adoption of new accounting principle and correction of an error in previously issued financial statements; (10) shares held in trust for Employee Stock Ownership Plan (ESOP); (11) deferred compensation related to issuance of capital stock; (12) note received for issuance of stock; (13) unamortized discount on shares; (14) description, terms, and number of warrants or rights outstanding; (15) shares under subscription and subscription receivables, effective date of new retained earnings after quasi-reorganization and deficit eliminated by quasi-reorganization and, for a period of at least ten years after the effective date, the point in time from which the new retained dates; and (16) retroactive effective of subsequent change in capital structure.

+ References

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+ Details

Comprehensive Income (Notes)

6 Months Ended

Jun. 30, 2011

Comprehensive Income [Abstract]

Comprehensive Income (Loss) Note [Text Block]

COMPREHENSIVE INCOME

Comprehensive income is as follows (in millions):



	Three Months Ended June 30,				Six Months Ended June 30,
	2011		2010		2011		2010
Net income	$	22	$	24	$	91	$	51
Other comprehensive income - Change in compensation retirement benefits liability and amortization, net of taxes	—		—		—		1
Comprehensive income and Comprehensive income attributable to Portland General Electric Company	$	22	$	24	$	91	$	52

Amounts included in Other comprehensive income related to the Company’s defined benefit pension plan and other postretirement benefits are reclassified to Regulatory assets as such amounts are expected to be recovered from retail customers in future prices. Accordingly, as of the balance sheet dates, such amounts are included in Regulatory assets. See Note 2.

In the second quarter of 2011, PGE changed the presentation of the Other comprehensive income item ‘reclassification of the defined pension plan and other benefits to a regulatory asset or liability’ to a net presentation. Accordingly, amounts previously reported on a gross basis for 2010 are presented net to conform with the 2011 presentation.

- Definition

The entire disclosure for comprehensive income. Includes, but is not limited to, the following: 1) the amount of income tax expense or benefit allocated to each component of other comprehensive income, including reclassification adjustments, 2) the reclassification adjustments for each classification of other comprehensive income and 3) the ending accumulated balances for each component of comprehensive income. Components of comprehensive income include: (1) foreign currency translation adjustments; (2) gains (losses) on foreign currency transactions that are designated as, and are effective as, economic hedges of a net investment in a foreign entity; (3) gains (losses) on intercompany foreign currency transactions that are of a long-term-investment nature, when the entities to the transaction are consolidated, combined, or accounted for by the equity method in the reporting enterprise's financial statements; (4) change in the market value of a futures contract that qualifies as a hedge of an asset reported at fair value; (5) unrealized holding gains (losses) on available-for-sale securities and that resulting from transfers of debt securities from the held-to-maturity category to the available-for-sale category; (6) a net loss recognized as an additional pension liability not yet recognized as net periodic pension cost; and (7) the net gain (loss) and net prior service cost or credit for pension plans and other postretirement benefit plans.

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+ Details

Contingencies (Notes)	6 Months Ended
Contingencies (Notes)	Jun. 30, 2011
Contingencies Note [Abstract]
CONTINGENCIES	CONTINGENCIES PGE is subject to legal, regulatory, and environmental proceedings, investigations, and claims that arise from time to time in the ordinary course of its business. The Company records accruals for such matters when it is probable that a liability will be incurred and the amount of loss can be reasonably estimated. When a loss contingency is not both probable and estimable, the Company does not record an accrual. However, if the loss (or an additional loss in excess of an accrual) is at least reasonably possible and material, then the Company (i) discloses an estimate of such loss or the range of such loss, if the Company is able to determine such an estimate, or (ii) discloses that an estimate cannot be made. The Company evaluates, on a quarterly basis, developments in such matters that could affect the amount of any accrual, as well as developments that would make a loss contingency both probable and reasonably estimable. The assessment as to whether a loss is probable or reasonably possible, and as to whether such loss or a range of such loss is estimable, often involves a series of complex judgments about future events. Management is often unable to estimate a reasonably possible loss, or a range of loss, particularly where (i) the damages sought are indeterminate or the basis for the damages claimed is not clear, (ii) the proceedings are in the early stages, (iii) discovery is not complete, (iv) the matters involve novel or unsettled legal theories, (v) there are significant facts in dispute, (vi) there are a large number of parties (including where it is uncertain how liability, if any, will be shared among multiple defendants) or (vii) there is a wide range of potential outcomes. In such cases, there is considerable uncertainty regarding the timing or ultimate resolution, including any possible loss, fine, penalty, or business impact. Trojan Investment Recovery In 1993, PGE closed the Trojan Nuclear Plant (Trojan) and sought full recovery of, and a rate of return on, its Trojan costs in a general rate case filing with the OPUC. The OPUC issued a general rate order that granted the Company recovery of, and a rate of return on, 87% of its remaining investment in Trojan. Court Proceedings on OPUC Authority to Grant Recovery of Return on Trojan Investment. Numerous challenges, appeals, and reviews were subsequently filed in various state courts on the issue of the OPUC’s authority under Oregon law to grant recovery of, and a return on, the Trojan investment. The primary plaintiffs in the litigation were the Citizens’ Utility Board (CUB) and the Utility Reform Project (URP). In 1998, the Oregon Court of Appeals upheld the OPUC’s order authorizing PGE’s recovery of the Trojan investment, but held that the OPUC did not have the authority to allow PGE to recover a return on the Trojan investment and remanded the case to the OPUC for reconsideration. In 2000, PGE, CUB, and the staff of the OPUC entered into agreements to settle the litigation related to PGE’s recovery of, and return on, its investment in Trojan. The URP did not participate in the settlement and filed a complaint with the OPUC challenging the settlement agreements. In March 2002, the OPUC issued an order (2002 Order) denying all of the URP’s challenges. In 2007, following several appeals by various parties, the Oregon Court of Appeals issued an opinion that remanded the 2002 Order to the OPUC for reconsideration. The OPUC then issued an order on September 30, 2008 that required PGE to refund $15.4 million, plus interest at 9.6% from September 30, 2000, to customers who received service from PGE during the period October 1, 2000 to September 30, 2001. The Company recorded a charge of $33.1 million as of September 30, 2008 related to the refund and accrued additional interest expense on the liability until refunds to customers were completed in the first quarter of 2010. The URP and the plaintiffs in the class actions described below have separately appealed the September 30, 2008 order to the Oregon Court of Appeals. These appeals remain pending. Class Actions. In a separate legal proceeding, two class action lawsuits were filed in Marion County Circuit Court against PGE in 2003 on behalf of two classes of electric service customers (the Class Action Plaintiffs). The lawsuits seek damages of $260 million, plus interest, as a result of PGE’s inclusion, in prices charged to customers, of a return on its investment in Trojan. In August 2006, the Oregon Supreme Court issued a ruling ordering the abatement of the class action proceedings until the OPUC responded to the 2002 Order (described above). The Oregon Supreme Court concluded that the OPUC has primary jurisdiction to determine what, if any, remedy it can offer to PGE customers, through price reductions or refunds, for any amount of return on the Trojan investment PGE collected in prices for the period from April 1, 1995 through October 1, 2000. The Oregon Supreme Court further stated that if the OPUC determined that it can provide a remedy to PGE’s customers, then the class action proceedings may become moot in whole or in part. The Oregon Supreme Court added that, if the OPUC determined that it cannot provide a remedy, the court system may have a role to play. The Oregon Supreme Court also ruled that the plaintiffs retain the right to return to the Marion County Circuit Court for disposition of whatever issues remain unresolved from the remanded OPUC proceedings. In October 2006, the Marion County Circuit Court abated the class actions in response to the ruling of the Oregon Supreme Court. Because the above matters involve unsettled legal theories and have a broad range of potential outcomes, management cannot predict the ultimate outcome or estimate a range of potential loss. Management believes, however, that these matters will not have a material adverse impact on the financial condition of the Company, but may have a material adverse impact on the results of operations and cash flows in future reporting periods. Complaint and Application for Deferral - Income Taxes On October 5, 2005, the URP and another party (together, the Complainants) filed a Complaint and an Application for Deferred Accounting with the OPUC alleging that, since the September 2, 2005 effective date of Oregon Senate Bill 408 (SB 408), PGE’s rates were not just and reasonable and were in violation of SB 408 because they contained approximately $92.6 million in annual charges for state and federal income taxes that are not being paid to any governmental entity. The Complaint and Application for Deferred Accounting requested that the OPUC order the creation of a deferred account for all amounts charged to customers since September 2, 2005 for state and federal income taxes, less amounts actually paid for income taxes by or on behalf of PGE to the federal and state governments. In August 2007, the OPUC issued an order granting the Application for Deferred Accounting for the period from October 5, 2005 through December 31, 2005 (Deferral Period). The OPUC’s order also dismissed the Complaint, on grounds that it was superfluous to the Complainants’ application for deferred accounting. The order required that PGE calculate the amounts applicable to the Deferral Period, earnings, and the effect of the deferral on the Company’s return on equity. In December 2007, PGE filed its report as required by the OPUC. In August 2009, the OPUC issued an order that indicated the deferral amount would be $26.5 million, but denied amortization of any deferral in this matter, based on a review of PGE’s earnings over the twelve month period ended September 30, 2006. In October 2009, Complainants filed an appeal of the August 2009 order with the Oregon Court of Appeals, which remains pending. Management cannot predict the ultimate outcome of this matter. Management believes, however, that this matter will not have a material adverse effect on PGE’s financial condition, results of operations or cash flows. Lawsuit filed by Sierra Club and Other Environmental Groups On September 30, 2008, the Sierra Club and other environmental groups filed suit against PGE in the U.S. District Court for the District of Oregon (Court) for alleged violations at PGE’s Boardman Coal Plant of the federal Clean Air Act (CAA), Oregon’s Regional Haze State Implementation Plan (SIP), the plant’s CAA Title V permit, and additional alleged violations of various environmental related regulations. The plaintiffs’ complaint sought injunctive relief, including permanently enjoining PGE from operating Boardman except in accordance with the CAA, Oregon’s SIP, and the plant’s Title V Permit. In addition, the complaint sought civil penalties against PGE including $27,500 per day per alleged violation for violations occurring before March 15, 2004 and $32,500 per day per alleged violation occurring thereafter. In July 2011, the parties reached a preliminary settlement and filed a consent decree with the Court that resolves all of the plaintiffs’ claims. The consent decree would require the Company to meet certain sulfur dioxide emission limits in operating Boardman and would allow for continued operation of Boardman through the end of 2020. In addition, the Company and the other Boardman co-owners will provide $2.5 million to the Oregon Community Foundation for environmental projects in the Columbia River Gorge and northeastern Oregon and pay $1 million to reimburse plaintiffs for legal expenses. The consent decree is subject to approval of the Court following a 45-day review period by the U.S. Environmental Protection Agency (EPA) and the U.S. Department of Justice. Management believes that the settlement will not have a material adverse effect on the Company’s financial condition, results of operations, or cash flows in future periods. During the second quarter of 2011, the Company accrued an expense of approximately $2 million as its share of the settlement. Payment of the settlement amounts is expected to occur following Court approval of the consent decree. EPA Notice of Violation In September 2010, PGE received a Notice of Violation (NOV) from the EPA. The NOV states that the EPA has determined that PGE is violating the New Source Performance Standards (NSPS) under the CAA, and Operating Permit requirements under Title V of the CAA, at the Boardman plant. In the NOV, the EPA asserts that certain projects at the Boardman plant in 1998 and in 2004 triggered the NSPS, that PGE did not meet the emissions standards required by the regulations, and that, therefore, PGE has operated the boiler at the Boardman plant in violation of the CAA. The NOV states the maximum civil penalties the EPA is authorized to impose under the CAA for violations of the NSPS (which range from $25,000 to $37,500 per day), but does not impose any penalties, or specify the amount of any proposed penalties with respect to the alleged violations. Accordingly, management cannot estimate the range of potential liability for the violations asserted in the NOV. However, based solely on the maximum penalties authorized under the CAA, management believes that the maximum penalty that could be imposed for the alleged violations is approximately $60 million. The projects alleged to have triggered the NSPS in the NOV are also included in the Sierra Club’s NSPS claim in the litigation described above. PGE believes that it has strong defenses to these claims. During the first quarter of 2011, PGE met with the EPA to confer about the violations cited and to present information on the specific findings of the EPA. PGE and the EPA agreed to continue the discussions. The EPA will also have the opportunity to submit comments to the Court on the Sierra Club settlement discussed above. Management cannot predict the ultimate outcome of this matter. Management believes, however, that this matter will not have a material adverse impact on the financial condition of the Company, but may have a material adverse impact on the results of operations and cash flows in future reporting periods. Pacific Northwest Refund Proceeding In July 2001, the FERC called for a hearing to explore whether there may have been unjust and unreasonable charges for spot market sales of electricity in the Pacific Northwest from December 25, 2000 through June 20, 2001 (Pacific Northwest Refund proceeding). During that period, PGE both sold and purchased electricity in the Pacific Northwest. In June 2003, the FERC issued an order terminating the proceeding and denying the claims for refunds. Parties appealed various aspects of the FERC order to the U.S. Ninth Circuit Court of Appeals (Ninth Circuit). In August 2007, the Ninth Circuit issued a decision, concluding that the FERC failed to adequately explain how it considered or examined new evidence showing intentional market manipulation in California and any potential ties to the Pacific Northwest and that the FERC should not have excluded from the Pacific Northwest Refund proceeding purchases of energy made by the California Energy Resources Scheduling (CERS) division in the Pacific Northwest spot market. The Ninth Circuit remanded the case to the FERC to: (i) address the new market manipulation evidence in detail and account for the evidence in any future orders regarding the award or denial of refunds in the proceedings; (ii) include sales to CERS in its analysis; and (iii) further consider its refund decision in light of related, intervening opinions of the court. The Ninth Circuit offered no opinion on the FERC’s findings based on the record established by the administrative law judge and did not rule on the FERC’s ultimate decision to deny refunds. After denying requests for rehearing, the Ninth Circuit in April 2009 issued a mandate giving immediate effect to its August 2007 order remanding the case to the FERC. Since issuance of the mandate, certain parties proposing refunds have filed pleadings with the FERC suggesting procedures on remand, attempting unsuccessfully to initiate new proceedings, and containing additional evidence that they assert shows market-wide manipulation that justifies refunds from early in 2000. Parties opposing refunds, including PGE, have filed various pleadings that contest allegations of market-wide manipulation and urge the FERC to reaffirm, with a more detailed explanation of its consideration of market manipulation claims, its previous decision not to initiate proceedings to order refunds. The settlement between PGE and certain other parties in the California refund case in Docket No. EL00-95, et seq., approved by the FERC in May 2007, resolved all claims between PGE and the California parties named in the settlement as to transactions in the Pacific Northwest during the settlement period, January 1, 2000 through June 21, 2001, but did not settle potential claims from other market participants relating to transactions in the Pacific Northwest. Management cannot predict the ultimate outcome of the Pacific Northwest Refund proceeding, whether the FERC will order refunds in this proceeding, which contracts would be subject to refunds, or how such refunds, if any, would be calculated. Accordingly, management cannot estimate a range of potential loss. Management believes, however, that the outcome will not have a material adverse impact on the financial condition of the Company, but may have a material adverse impact on PGE’s results of operations and cash flows in future reporting periods. EPA Investigation of Portland Harbor A 1997 investigation by the EPA of a segment of the Willamette River known as Portland Harbor revealed significant contamination of river sediments. The EPA subsequently included Portland Harbor on the National Priority List pursuant to the federal Comprehensive Environmental Response, Compensation, and Liability Act as a federal Superfund site and listed 69 Potentially Responsible Parties (PRPs). PGE was included among the PRPs as it has historically owned or operated property near the river. The Portland Harbor site is currently undergoing a remedial investigation and feasibility study (RI/FS) pursuant to an Administrative Order on Consent (AOC) between the EPA and several PRPs, not including PGE. In the AOC, the EPA determined that the RI/FS would focus on a segment of the river approximately 5.7 miles in length. In January 2008, the EPA requested information from various parties, including PGE, concerning properties in or near the 5.7 mile segment of the river being examined in the RI/FS, as well as several miles beyond. Subsequently, the EPA has listed additional PRPs, which now number over one hundred. The EPA will determine the boundaries of the site at the conclusion of the RI/FS in a Record of Decision in which it will document its findings and select a preferred cleanup alternative. The EPA expects to issue the Record of Decision in 2012. Sufficient information is currently not available to determine the total cost of any required investigation or remediation of the Portland Harbor site or the liability of PRPs, including PGE. Management cannot predict the ultimate outcome of this matter or estimate a range of potential loss. Management believes, however, that the outcome will not have a material adverse impact on the financial condition of the Company, but may have a material adverse impact on PGE’s results of operations and cash flows in future reporting periods. EPA Investigation of Harbor Oil Harbor Oil, Inc. (Harbor Oil), located in north Portland, was utilized by PGE to process used oil from the Company’s power plants and electrical distribution system from at least 1990 until 2003. Harbor Oil continues to be utilized by other entities for the processing of used oil and other lubricants. In 1974 and 1979, major oil spills occurred at the Harbor Oil site. Elevated levels of contaminants, including metals, pesticides, and polychlorinated biphenyls, have been detected at the site. In September 2003, the EPA included the Harbor Oil facility on the National Priority List as a federal Superfund site. PGE received a Special Notice Letter for RI/FS from the EPA, dated June 27, 2005, in which the Company was named as one of fourteen PRPs with respect to the Harbor Oil site. In May 2007, an AOC was signed by the EPA and six other parties, including PGE, to implement an RI/FS at the Harbor Oil site. The draft remedial investigation was completed with the resulting report submitted to the EPA. Sufficient information is currently not available to determine the total cost of investigation and remediation of the Harbor Oil site or the liability of the PRPs, including PGE. Management cannot predict the ultimate outcome of this matter or estimate a range of potential loss. Management believes, however, that the outcome of this matter will not have a material adverse impact on the financial condition of the Company, but may have a material adverse impact on PGE’s results of operations and cash flows in future reporting periods. Revenue Bonds In 2008, PGE repurchased $5.8 million of Pollution Control Revenue Bonds Series 1996 (Bonds) issued through the Port of Morrow, which was paid to Lehman Brothers Inc. (Lehman) as remarketing agent for the Bonds, who in turn paid off the beneficial owner of the Bonds. As a result of the payment, PGE became the beneficial owner of the Bonds and requested that Lehman safe-keep the Bonds in Lehman’s Depository Trust Company participant account until such time as the Bonds could be remarketed. After repurchase of the Bonds, PGE removed the liability for the Bonds from its financial statements. In September 2008, Lehman filed for protection under Chapter 11 of the U.S. Bankruptcy Code. PGE subsequently filed a claim for return of the Bonds from Lehman. On November 9, 2009, the trustee appointed to liquidate the assets of Lehman (Trustee) allowed PGE’s claim as a net equity claim for securities. At the time, PGE believed it would receive back the entire amount of the Bonds at some point during the bankruptcy proceedings. It is not certain that the Company will receive the full amount of the Bonds but could, along with other claimants, potentially receive a pro-rata share of certain assets. The timing and extent of distributions on claims are subject to the ultimate disposition of numerous claims in the proceedings and certain major contingencies which the Trustee must resolve. PGE cannot currently estimate how much of the value of the Bonds will ultimately be returned to the Company or the timing of the distribution from Lehman. Management does not expect the outcome of this matter to have a material adverse impact on the Company’s financial condition, but it may have a material adverse impact on PGE’s results of operations and cash flows for a future reporting period. Other Matters PGE is subject to other regulatory, environmental, and legal proceedings, investigations, and claims that arise from time to time in the ordinary course of its business, which may result in adverse judgments against the Company. Although management currently believes that resolution of such matters will not have a material adverse effect on its financial position, results of operations, or cash flows, these matters are subject to inherent uncertainties and management’s view of these matters may change in the future.

- Definition

The entire disclosure for commitments and contingencies.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 14
-Paragraph 3
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 5
-Paragraph 9, 10, 11, 12
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.25)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 450
-SubTopic 20
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6952336&loc=d3e14435-108349

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 460
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6398077&loc=d3e12565-110249

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 440
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6394976&loc=d3e25287-109308

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6449706&loc=d3e16207-108621

+ Details

Guarantees (Notes)	6 Months Ended
Guarantees (Notes)	Jun. 30, 2011
Guarantees Note [Abstract]
GUARANTEES	GUARANTEES PGE enters into financial agreements and power and natural gas purchase and sale agreements that include indemnification provisions relating to certain claims or liabilities that may arise relating to the transactions contemplated by these agreements. Generally, a maximum obligation is not explicitly stated in the indemnification provisions and, therefore, the overall maximum amount of the obligation under such indemnifications cannot be reasonably estimated. PGE periodically evaluates the likelihood of incurring costs under such indemnities based on PGE’s historical experience and the evaluation of the specific indemnities. As of June 30, 2011, management believes the likelihood is remote that PGE would be required to perform under such indemnification provisions or otherwise incur any significant losses with respect to such indemnities. The Company has not recorded any liability on the condensed consolidated balance sheets with respect to these indemnities.

- Definition

Tabular disclosure of each guarantee obligation, or each group of similar guarantee obligations, including (a) the nature of the guarantee, including its term, how it arose, and the events or circumstances that would require the guarantor to perform under the guarantee; (b) the maximum potential amount of future payments (undiscounted) the guarantor could be required to make under the guarantee; (c) the current carrying amount of the liability, if any, for the guarantor's obligations under the guarantee; and (d) the nature of any recourse provisions under the guarantee, and any assets held either as collateral or by third parties, and any relevant related party disclosure. Excludes disclosures about product warranties.

+ References + Details

Variable Interest Entities (Notes)

6 Months Ended

Jun. 30, 2011

Variable Interest Entities Note [Abstract]

VariableInterestEntities [Text Block]

VARIABLE INTEREST ENTITIES

PGE has determined that it is the primary beneficiary of three variable interest entities (VIEs) and, therefore, consolidates the VIEs within the Company’s condensed consolidated financial statements. All three arrangements were formed for the sole purpose of designing, developing, constructing, owning, maintaining, operating, and financing photovoltaic solar power facilities located on real property owned by third parties and selling the energy generated by the facilities. PGE is the Managing Member in each of the Limited Liability Companies (LLCs), holding less than 1% equity interest in each entity, and a financial institution is the Investor Member, holding more than 99% equity interest in each entity. The Company has determined that its interests in these VIEs contain the obligation to absorb the variability of the entities that could potentially be significant to the VIEs, and PGE has the power to direct the activities that most significantly affect the entities' economic performance.

Determining whether PGE is the primary beneficiary of a VIE is complex, subjective and requires the use of judgments and assumptions. Significant judgments and assumptions made by PGE in determining it is the primary beneficiary of these LLCs include the following: (1) PGE has the expertise to own and operate electric generating facilities and is authorized to operate the LLCs pursuant to the operating agreements, and, therefore, PGE has control over the most significant activities of the LLCs; (2) PGE expects to own 100% of the LLCs shortly after five years have elapsed, at which time the facilities will have approximately 75% of their estimated useful life remaining; and (3) based on projections prepared in accordance with the operating agreements, PGE expects to absorb a majority of the expected losses of the LLCs.

Included in PGE’s condensed consolidated balance sheet are LLC net assets as follows (in millions):



	June 30, 2011		December 31 2010
Cash and cash equivalents	$	—	$	1
Accounts receivable, net	—		4
Electric utility plant, net	5		5

These assets can only be used to settle the obligations of the consolidated VIEs.

Basis of Presentation (Policies)	6 Months Ended
Basis of Presentation (Policies)	Jun. 30, 2011
Basis of Presentation [Abstract]
Consolidation, Policy [Policy Text Block]	These condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). Certain information and footnote disclosures normally included in financial statements prepared in conformity with accounting principles generally accepted in the United States of America (GAAP) have been condensed or omitted pursuant to such regulations,

- Definition

Disclosure of accounting policy regarding (1) the principles it follows in consolidating or combining the separate financial statements, including the principles followed in determining the inclusion or exclusion of subsidiaries or other entities in the consolidated or combined financial statements and (2) its treatment of interests (for example, common stock, a partnership interest or other means of exerting influence) in other entities, for example consolidation or use of the equity or cost methods of accounting. The accounting policy may also address the accounting treatment for intercompany accounts and transactions, noncontrolling interest, and the income statement treatment in consolidation for issuances of stock by a subsidiary.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 140
-Paragraph 46
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 2-6
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 46R
-Paragraph 14, 15
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Principles Board Opinion (APB)
-Number 18
-Paragraph 5, 6, 16-19
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Principles Board Opinion (APB)
-Number 18
-Paragraph 20
-Subparagraph a(2)
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number 96-16
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number 97-2
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Article 3A
-Section 02, 03

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph k
-Article 1

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 46R
-Paragraph 4
-Subparagraph c
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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-Subparagraph d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6367646&loc=d3e18780-107790

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 860
-SubTopic 40
-Section 45
-URI http://asc.fasb.org/section&trid=2197723

Reference 14: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 810
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-URI http://asc.fasb.org/subtopic&trid=2197480

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-Name Accounting Standards Codification
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-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.3A-02)
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Reference 17: http://www.xbrl.org/2003/role/presentationRef
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Reference 19: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-URI http://asc.fasb.org/subtopic&trid=2197087

+ Details

Balance Sheet Components (Policies)	6 Months Ended
Balance Sheet Components (Policies)	Jun. 30, 2011
Balance Sheet Components [Abstract]
Inventory, Policy [Policy Text Block]	Materials and supplies inventories are used in operations and maintenance and capital activities, and are recorded at average cost. Fuel inventories include natural gas, coal, and oil and are used in PGE’s generating plants. Natural gas is recorded at the lower of average cost or market, with coal and oil recorded at average cost.

- Definition

Disclosure of accounting policy for major classes of inventories, bases of stating inventories (for example, lower of cost or market), methods by which amounts are added and removed from inventory classes (for example, FIFO, LIFO, or average cost), loss recognition on impairment of inventories, and situations in which inventories are stated above cost. If inventory is carried at cost, this disclosure includes the nature of the cost elements included in inventory.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph 6
-Subparagraph a
-Article 5

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 43
-Chapter 3
-Section A
-Paragraph 9
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Statement of Position (SOP)
-Number 81-1
-Paragraph 69-75
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Financial Reporting Release (FRR)
-Number 206
-Chapter 2
-Paragraph b
-Subparagraph i, ii

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 43
-Chapter 4
-Paragraph 3, 5-10, 15, 16, 17
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6367646&loc=d3e18780-107790

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6361739&loc=d3e7789-107766

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.6(b))
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 330
-SubTopic 10
-URI http://asc.fasb.org/subtopic&trid=2126999

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-Publisher FASB
-Name Accounting Standards Codification
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-Topic 330
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6386783&loc=d3e4556-108314

+ Details

Fair Value of Financial Instruments (Policies)

6 Months Ended

Jun. 30, 2011

Fair Value of Financial Instruments [Abstract]

fair value determination [Policy Text Block]


•	Derivative instruments are recorded at fair value and are based on published market indices, which may be adjusted for market variables such as location pricing differences and/or the effects of liquidity at different locations. The Company also values certain derivative instruments using either standardized or internally developed models;


•	Certain trust assets, consisting of money market funds and fixed income securities included in the Nuclear decommissioning trust and marketable securities included in the Non-qualified benefit plan trust, are recorded at fair value and are based on quoted market prices; and


•	The fair value of long-term debt is estimated based on the quoted market prices for the same or similar issues or on the current rates offered to PGE for debt of similar remaining maturities.

Price Risk Management (Policies)	6 Months Ended
Price Risk Management (Policies)	Jun. 30, 2011
Price Risk Management [Abstract]
Derivatives, Policy [Policy Text Block]	PGE utilizes derivative instruments in its wholesale electric utility activities to manage its exposure to commodity price risk and foreign currency exchange rate risk, mitigate the effects of market fluctuations, and minimize net power costs for service to its retail customers. These derivative instruments may include forward, swap, and option contracts for electricity, natural gas, oil, and foreign currency, and futures contracts for natural gas and oil. All derivative instruments are recorded at fair value on the balance sheet, with changes in fair value recorded in the statement of income. However, as a regulated entity, PGE recognizes a regulatory asset or liability in order to defer gains and losses from derivative activity until realized, in accordance with the ratemaking and cost recovery process authorized by the OPUC. This accounting treatment defers the mark-to-market gains and losses on derivative activities until settlement. PGE may designate certain derivative instruments as cash flow hedges or may use derivative instruments as purely economic hedges. PGE does not engage in trading activities for non-retail purposes. PGE has elected to report gross on the balance sheet the positive and negative exposures resulting from derivative instruments entered into with counterparties where a master netting arrangement exists.

- Definition

Disclosure of accounting policy for its derivative instruments and hedging activities. Disclosure may include: (1) Each method used to account for derivative financial instruments and derivative commodity instruments ("derivatives"); (2) the types of derivatives accounted for under each method; (3) the criteria required to be met for each accounting method used, including a discussion of the criteria required to be met for hedge or deferral accounting and accrual or settlement accounting (for example, whether and how risk reduction, correlation, designation, and effectiveness tests are applied); (4) the accounting method used if the criteria specified for hedge accounting are not met; (5) the method used to account for termination of derivatives designated as hedges or derivatives used to affect directly or indirectly the terms, fair values, or cash flows of a designated item; (6) the method used to account for derivatives when the designated item matures, is sold, is extinguished, or is terminated. In addition, the method used to account for derivatives designated to an anticipated transaction, when the anticipated transaction is no longer likely to occur; and (7) where and when derivatives, and their related gains or losses are reported in the statement of financial position, cash flows, and results of operations and (8) an accounting policy decision to offset fair value amounts with counterparties. An entity may also describe its embedded derivatives, and the method(s) used to determine the fair values of derivatives and any significant assumptions used in such valuations.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 44
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph n
-Article 4

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 39
-Paragraph 10
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-Name Accounting Standards Codification
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-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n))
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-SubTopic 10
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-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=6935481&loc=d3e41675-113959

+ Details

Earnings Per Share (Policies)	6 Months Ended
Earnings Per Share (Policies)	Jun. 30, 2011
Earnings Per Share [Abstract]
Earnings Per Share, Policy [Policy Text Block]	Unvested performance stock units and related dividend equivalent rights are not included in the computation of dilutive securities because vesting of these instruments is dependent upon three-year performance periods and the vesting criteria have not been met as of the end of the reporting period presented.

- Definition

Disclosure of accounting policy for computing basic and diluted earnings or loss per share for each class of common stock and participating security. Addresses all significant policy factors, including any antidilutive items that have been excluded from the computation and takes into account stock dividends, splits and reverse splits that occur after the balance sheet date of the latest reporting period but before the issuance of the financial statements.

+ References + Details

Contingencies (Policies)	6 Months Ended
Contingencies (Policies)	Jun. 30, 2011
Contingencies [Abstract]
Commitments and Contingencies, Policy [Policy Text Block]	PGE is subject to legal, regulatory, and environmental proceedings, investigations, and claims that arise from time to time in the ordinary course of its business. The Company records accruals for such matters when it is probable that a liability will be incurred and the amount of loss can be reasonably estimated. When a loss contingency is not both probable and estimable, the Company does not record an accrual. However, if the loss (or an additional loss in excess of an accrual) is at least reasonably possible and material, then the Company (i) discloses an estimate of such loss or the range of such loss, if the Company is able to determine such an estimate, or (ii) discloses that an estimate cannot be made. The Company evaluates, on a quarterly basis, developments in such matters that could affect the amount of any accrual, as well as developments that would make a loss contingency both probable and reasonably estimable. The assessment as to whether a loss is probable or reasonably possible, and as to whether such loss or a range of such loss is estimable, often involves a series of complex judgments about future events. Management is often unable to estimate a reasonably possible loss, or a range of loss, particularly where (i) the damages sought are indeterminate or the basis for the damages claimed is not clear, (ii) the proceedings are in the early stages, (iii) discovery is not complete, (iv) the matters involve novel or unsettled legal theories, (v) there are significant facts in dispute, (vi) there are a large number of parties (including where it is uncertain how liability, if any, will be shared among multiple defendants) or (vii) there is a wide range of potential outcomes. In such cases, there is considerable uncertainty regarding the timing or ultimate resolution, including any possible loss, fine, penalty, or business impact.

- Definition

Disclosure of accounting policy for commitments and contingencies, which may include policies for recognizing and measuring loss and gain contingencies.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 5
-Paragraph 9
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Principles Board Opinion (APB)
-Number 22
-Paragraph 8
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Audit and Accounting Guide (AAG)
-Number AAG-HCO
-Chapter 8
-Paragraph 12, 13
-IssueDate 2006-05-01
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 45
-Paragraph 3
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6367646&loc=d3e18780-107790

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 954
-SubTopic 450
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6491354&loc=d3e6049-115624

Reference 7: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 460
-SubTopic 10
-Section 50
-Paragraph 8
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=6398077&loc=d3e12565-110249

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-Name Accounting Standards Codification
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-Paragraph 2
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Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/subtopic&trid=2155897

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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-Paragraph 8
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 11: http://www.xbrl.org/2003/role/presentationRef
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-Paragraph 9
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 45
-Paragraph 10
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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-Paragraph 11
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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-Paragraph 12
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

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Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Technical Bulletin (FTB)
-Paragraph 3
-Number 90-1
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 17: http://www.xbrl.org/2003/role/presentationRef
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-Name FASB Technical Bulletin (FTB)
-Number 90-1
-Paragraph 4
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 18: http://www.xbrl.org/2003/role/presentationRef
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-Name FASB Technical Bulletin (FTB)
-Number 90-1
-Paragraph 5
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 19: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 5
-Paragraph 24
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 20: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 5
-Paragraph 25
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 21: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 5
-Paragraph 26
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Guarantees (Policies)	6 Months Ended
Guarantees (Policies)	Jun. 30, 2011
Guarantees [Abstract]
Guarantees, Indemnifications and Warranties Policies [Policy Text Block]	Generally, a maximum obligation is not explicitly stated in the indemnification provisions and, therefore, the overall maximum amount of the obligation under such indemnifications cannot be reasonably estimated. PGE periodically evaluates the likelihood of incurring costs under such indemnities based on PGE’s historical experience and the evaluation of the specific indemnities.

- Definition

Disclosure of accounting policy for guarantees, indemnifications and product warranties, and methodologies used in determining the amount of such liabilities.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 45
-Paragraph 3, 8-12, 14
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Technical Bulletin (FTB)
-Number 90-1
-Paragraph 3-5
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 5
-Paragraph 24, 25, 26
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6367646&loc=d3e18780-107790

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 460
-SubTopic 10
-Section 50
-Paragraph 8
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=6398077&loc=d3e12565-110249

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 460
-SubTopic 10
-URI http://asc.fasb.org/subtopic&trid=2155897

+ Details

Variable interest entities (Policies)	6 Months Ended
Variable interest entities (Policies)	Jun. 30, 2011
Variable interest Entities [Abstract]
Consolidation, Variable Interest Entity, Policy [Policy Text Block]	PGE has determined that it is the primary beneficiary of three variable interest entities (VIEs) and, therefore, consolidates the VIEs within the Company’s condensed consolidated financial statements.

- Definition

Disclosure of accounting policy for consolidation to describe the significant judgments and assumptions made in determining whether a variable interest held by the entity requires the variable interest entity to be consolidated and (or) disclose information about its involvement with the variable interest entity; the methodology used by the entity for determining whether or not it is the primary beneficiary of the variable interest entity; and the significant factors considered and judgments made in determining that the power to direct the activities that significantly impact the economic performance of the variable interest entity are shared (as defined).

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 46R
-Paragraph 14, 15
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section 50
-Paragraph 3
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Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-URI http://asc.fasb.org/subtopic&trid=2197480

Reference 4: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-Subparagraph (e)
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-Name Accounting Standards Codification
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-Section 50
-Paragraph 5A
-Subparagraph (a)
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Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 167
-Appendix D
-Paragraph 22B
-Subparagraph a

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 167
-Appendix D
-Paragraph 22E
-Subparagraph a

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 167
-Appendix D
-Paragraph 24
-Subparagraph e

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 2AA
-Subparagraph a
-URI http://asc.fasb.org/extlink&oid=6970148&loc=SL6759068-111685

+ Details

Balance Sheet Components (Tables)

6 Months Ended

Jun. 30, 2011

Balance Sheet Components [Abstract]

Schedule of Valuation and Qualifying Accounts Disclosure [Text Block]

The activity in the allowance for uncollectible accounts is as follows (in millions):



	Six Months Ended June 30,
	2011			2010
Balance as of beginning of period	$	5		$	5
Provision, net	3			3
Amounts written off, less recoveries	(3		)	(3		)
Balance as of end of period	$	5		$	5

Schedule of Public Utility Property, Plant, and Equipment [Table Text Block]

Electric utility plant, net consists of the following (in millions):



	June 30, 2011			December 31, 2010
Electric utility plant	$	6,458		$	6,279
Construction work in progress	121			125
Total cost	6,579			6,404
Less: accumulated depreciation and amortization	(2,352		)	(2,271		)
Electric utility plant, net	$	4,227		$	4,133

Schedule of Regulatory Assets and Liabilities [Text Block]

Regulatory assets and liabilities consist of the following (in millions):



	June 30, 2011				December 31, 2010
	Current		Noncurrent		Current		Noncurrent
Regulatory assets:
Price risk management	$	153	$	142	$	175	$	185
Pension and other postretirement plans	—		207		—		213
Deferred income taxes	—		91		—		95
Deferred broker settlements	12		—		24		—
Renewable energy deferral	12		—		22		—
Debt reacquisition costs	—		22		—		23
Other	7		19		—		28
Total regulatory assets	$	184	$	481	$	221	$	544
Regulatory liabilities:
Asset retirement removal costs	$	—	$	612	$	—	$	588
Asset retirement obligations	—		34		—		33
Power cost adjustment mechanism	—		12		—		—
Regulatory treatment of income taxes (SB 408)	8		1		5		9
Trojan ISFSI pollution control tax credits	9		5		18		4
Other	2		28		2		23
Total regulatory liabilities	$	19	$	692	$	25	$	657

Other Liabilities Disclosure [Text Block]

Other current liabilities consist of the following (in millions):



	June 30, 2011		December 31, 2010
Accrued interest payable	$	26	$	26
Accrued taxes payable	19		22
Accrued dividends payable	21		20
Other	8		10
Total other current liabilities	$	74	$	78

Pension and Other Postretirement Benefits Disclosure [Text Block]

Components of net periodic benefit cost are as follows for the three months ended June 30 (in millions):



	Defined Benefit Pension Plan						Other Postretirement Benefit Plans				Non-Qualified Benefit Plans
	2011			2010			2011		2010		2011		2010
Service cost	$	3		$	3		$	—	$	—	$	—	$	—
Interest cost	7			7			1		1		—		—
Expected return on plan assets	(10		)	(10		)	—		—		—		—
Amortization of net actuarial gain	2			1			—		1		—		—
Net periodic benefit cost	$	2		$	1		$	1	$	2	$	—	$	—

Components of net periodic benefit cost are as follows for the six months ended June 30 (in millions):



	Defined Benefit Pension Plan						Other Postretirement Benefit Plans				Non-Qualified Benefit Plans
	2011			2010			2011		2010		2011		2010
Service cost	$	6		$	6		$	1	$	1	$	—	$	—
Interest cost	14			14			2		2		1		1
Expected return on plan assets	(20		)	(20		)	—		—		—		—
Amortization of net actuarial gain	4			2			—		1		—		—
Net periodic benefit cost	$	4		$	2		$	3	$	4	$	1	$	1

- Definition

The entire disclosure for pension and other postretirement benefits.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph h
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Reference 4: http://www.xbrl.org/2003/role/presentationRef
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-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
-Subparagraph q
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Reference 5: http://www.xbrl.org/2003/role/presentationRef
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-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
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Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 106
-Paragraph 518
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 87
-Paragraph 264
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
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-Number 03-2
-Paragraph 8
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Principles Board Opinion (APB)
-Number 30
-Paragraph 26
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 10: http://www.xbrl.org/2003/role/presentationRef
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-Paragraph 20, 21, 22
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Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 158
-Paragraph 7, 21, 22
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5, 6, 7, 8
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Implementation Guide (Q and A)
-Number FAS88
-Paragraph 63
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-URI http://asc.fasb.org/topic&trid=2235017

+ Details

Fair Value of Financial Instruments (Tables)

6 Months Ended

Jun. 30, 2011

^[2]

Fair Value of Financial Instruments [Abstract]

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]

The Company’s financial assets and liabilities whose values were recognized at fair value are as follows by level within the fair value hierarchy (in millions):



	As of June 30, 2011
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trust ⁽¹⁾:
Money market funds	$	—	$	14	$	—	$	14
Debt securities:
U.S. treasury securities	8		—		—		8
Corporate debt securities	—		5		—		5
Mortgage-backed securities	—		6		—		6
Municipal securities	—		2		—		2
Asset-backed securities	—		1		—		1
Non-qualified benefit plan trust ⁽²⁾:
Equity securities:
Mutual funds	13		1		—		14
Common stocks	2		—		—		2
Debt securities - mutual funds	3		—		—		3
Assets from price risk management activities ^{(1) (3)}:
Electricity	—		6		1		7
Natural gas	—		3		—		3
	$	26	$	38	$	1	$	65
Liabilities - Liabilities from price risk management activities ^{(1) (3)}:
Electricity	$	—	$	68	$	25	$	93
Natural gas	—		110		103		213
	$	—	$	178	$	128	$	306


(1)	Activities are subject to regulation, with certain gains and losses deferred pursuant to regulatory accounting and included in Regulatory assets or Regulatory liabilities as appropriate.


(2)	Excludes insurance policies of $23 million, which are recorded at cash surrender value.


(3)	For further information, see Note 4, Price Risk Management.



	As of December 31, 2010
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trust ⁽¹⁾:
Money market funds	$	—	$	13	$	—	$	13
Debt securities:
U.S. treasury securities	3		—		—		3
Corporate debt securities	—		6		—		6
Mortgage-backed securities	—		7		—		7
Municipal securities	—		4		—		4
Asset-backed securities	—		1		—		1
Non-qualified benefit plan trust ⁽²⁾:
Equity securities:
Mutual funds	16		1		—		17
Common stocks	2		—		—		2
Debt securities - mutual funds	2		—		—		2
Assets from price risk management activities ^{(1) (3)}:
Electricity	—		4		1		5
Natural gas	—		11		—		11
	$	23	$	47	$	1	$	71
Liabilities - Liabilities from price risk management activities ^{(1) (3)}:
Electricity	$	—	$	102	$	17	$	119
Natural gas	—		153		104		257
	$	—	$	255	$	121	$	376


(1)	Activities are subject to regulation, with certain gains and losses deferred pursuant to regulatory accounting and included in Regulatory assets or Regulatory liabilities as appropriate.


(2)	Excludes insurance policies of $23 million, which are recorded at cash surrender value.


(3)	For further information, see Note 4, Price Risk Management.

^[1]

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]



	Three Months		Six Months
	Ended June 30,		Ended June 30,
	2011		2011
Net liabilities from price risk management activities as of beginning of period	$	116	$	120
Realized and unrealized (gains) and losses, net	10		8
Purchases	1		—
Settlements	—		(1		)
Net liabilities from price risk management activities as of end of period	$	127	$	127

	Three Months		Six Months
	Ended June 30,		Ended June 30,
	2010		2010
Net liabilities from price risk management activities as of beginning of period	$	221	$	154
Realized and unrealized (gains) and losses, net	2		59
Purchases, issuances and settlements, net	2		12
Net liabilities from price risk management activities as of end of period	$	225	$	225

[1]	(1)Activities are subject to regulation, with certain gains and losses deferred pursuant to regulatory accounting and included in Regulatory assets or Regulatory liabilities as appropriate.(2)Excludes insurance policies of $23 million, which are recorded at cash surrender value.(3)For further information, see Note 4, Price Risk Management.
[2]	(1)Activities are subject to regulation, with certain gains and losses deferred pursuant to regulatory accounting and included in Regulatory assets or Regulatory liabilities as appropriate.(2)Excludes insurance policies of $23 million, which are recorded at cash surrender value.(3)For further information, see Note 4, Price Risk Management.

- Definition

Tabular disclosure of the fair value measurement of assets using significant unobservable inputs (Level 3), a reconciliation of the beginning and ending balances, separately presenting changes during the period attributable to the following: (1) total gains or losses for the period (realized and unrealized), segregating those gains or losses included in earnings (or changes in net assets) and gains or losses recognized in other comprehensive income, and a description of where those gains or losses included in earnings (or changes in net assets) are reported in the statement of income (or activities); (2) purchases, sales, issuances, and settlements (each type disclosed separately); and (3) transfers in and transfers out of Level 3 (for example, transfers due to changes in the observability of significant inputs), by class of asset.

+ References + Details

Price Risk Management (Tables)

6 Months Ended

Jun. 30, 2011

Derivative [Line Items]

Schedule of Derivative Instruments [Table Text Block]

PGE’s net volumes related to its Assets and Liabilities from price risk management activities resulting from its derivative transactions were as follows (in millions):



	June 30, 2011			December 31, 2010
Commodity contracts:
Electricity	12		MWh	9		MWh
Natural gas	82		Decatherms	93		Decatherms
Foreign currency	$	11	Canadian	$	7	Canadian

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]

The fair value of PGE’s Assets and Liabilities from price risk management activities consists of the following (in millions):



	June 30, 2011			December 31, 2010
Current assets:
Commodity contracts:
Electricity	$	6		$	4
Natural gas	3			9
Total current derivative assets	9		⁽¹⁾	13		⁽¹⁾
Noncurrent assets:
Commodity contracts:
Electricity	1			1
Natural gas	—			2
Total noncurrent derivative assets	1		⁽²⁾	3		⁽²⁾
Total derivative assets not designated as hedging instruments	$	10		$	16
Total derivative assets	$	10		$	16
Current liabilities:
Commodity contracts:
Electricity	$	56		$	77
Natural gas	107			111
Total current derivative liabilities	163			188
Noncurrent liabilities:
Commodity contracts:
Electricity	37			42
Natural gas	106			146
Total noncurrent derivative liabilities	143			188
Total derivative liabilities not designated as hedging instruments	$	306		$	376
Total derivative liabilities	$	306		$	376


(1)	Included in Other current assets on the condensed consolidated balance sheets.


(2)	Included in Other noncurrent assets on the condensed consolidated balance sheets.

Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location [Table Text Block]



	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010
Commodity contracts:
Electricity	$	1		$	(6	)	$	(31	)	$	(59	)
Natural Gas	(17		)	(18		)	(11		)	(109		)

Schedule of Price Risk Derivatives [Table Text Block]



	2011		2012		2013		2014		2015		Total
Commodity contracts:
Electricity	$	22	$	39	$	18	$	7	$	—	$	86
Natural gas	56		97		46		10		1		210
Net unrealized loss	$	78	$	136	$	64	$	17	$	1	$	296

Schedule of Concentration of Risk, by Counterparty [Table Text Block]

Counterparties representing 10% or more of Assets and Liabilities from price risk management activities as of June 30, 2011 or December 31, 2010 were as follows:



	June 30, 2011		December 31, 2010
Assets from price risk management activities:
Counterparty A	24	%	22	%
Counterparty B	13		11
Counterparty C	12		23
Counterparty D	10		1
Counterparty E	—		10
	59	%	67	%
Liabilities from price risk management activities:
Counterparty C	25	%	24	%
Counterparty F	10		9
Counterparty G	9		12
	44	%	45	%

- Definition

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5579245-113959

Reference 2: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5624163-113959

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4C
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5624171-113959

Reference 4: http://www.xbrl.org/2003/role/presentationRef
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-Paragraph 8
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Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n)(2))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

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-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6886632&loc=d3e76258-113986

+ Details

Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2011

Components of Earnings per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]

Components of basic and diluted earnings per share were as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2011		2010		2011		2010
Numerator (in millions):
Net income attributable to Portland General Electric Company common shareholders	$	22	$	24	$	91	$	51
Denominator (in thousands):
Weighted-average common shares outstanding - basic	75,326		75,276		75,322		75,253
Dilutive effect of unvested restricted stock units and employee stock purchase plan shares	75		14		47		15
Weighted-average common shares outstanding - diluted	75,401		75,290		75,369		75,268
Earnings per share:
Basic	$	0.29	$	0.32	$	1.21	$	0.68
Diluted	$	0.29	$	0.32	$	1.21	$	0.68

Equity (Tables)

6 Months Ended

Jun. 30, 2011

Equity [Abstract]

Schedule of Stockholders Equity [Table Text Block]

The activity in equity during the six months ended June 30, 2011 and 2010 is as follows (dollars in millions):



	Portland General Electric Company Shareholders’ Equity
	Common Stock			Accumulated Other Comprehensive Loss			Retained Earnings			Noncontrolling Interests’ Equity
	Shares	Amount		Accumulated Other Comprehensive Loss			Retained Earnings			Noncontrolling Interests’ Equity
Balances as of December 31, 2010	75,316,419	$	831	$	(5	)	$	766		$	7
Vesting of restricted stock units	12,104	—		—			—			—
Issuance of shares pursuant to employee stock purchase plan	11,320	—		—			—			—
Issuance of shares pursuant to dividend reinvestment and direct stock purchase plan	1,261	—		—			—			—
Stock-based compensation	—	1		—			—			—
Dividends declared	—	—		—			(39		)	—
Capital distribution	—	—		—			—			(4		)
Net income	—	—		—			91			—
Balances as of June 30, 2011	75,341,104	$	832	$	(5	)	$	818		$	3

Balances as of December 31, 2009	75,210,580	$	829	$	(6	)	$	719		$	1
Vesting of restricted and performance stock units	69,561	—		—			—			—
Issuance of shares pursuant to employee stock purchase plan	14,846	—		—			—			—
Stock-based compensation	—	1		—			—			—
Dividends declared	—	—		—			(39		)	—
Net income	—	—		—			51			—
Other comprehensive income	—	—		1			—			—
Balances as of June 30, 2010	75,294,987	$	830	$	(5	)	$	731		$	1

Comprehensive Income (Tables)

6 Months Ended

Jun. 30, 2011

Comprehensive Income [Abstract]

Schedule of Comprehensive Income (Loss) [Table Text Block]

Comprehensive income is as follows (in millions):



	Three Months Ended June 30,				Six Months Ended June 30,
	2011		2010		2011		2010
Net income	$	22	$	24	$	91	$	51
Other comprehensive income - Change in compensation retirement benefits liability and amortization, net of taxes	—		—		—		1
Comprehensive income and Comprehensive income attributable to Portland General Electric Company	$	22	$	24	$	91	$	52

Variable Interest Entities (Tables)

6 Months Ended

Jun. 30, 2011

Variable interest Entities [Abstract]

Schedule of Variable Interest Entities [Table Text Block]

Included in PGE’s condensed consolidated balance sheet are LLC net assets as follows (in millions):



	June 30, 2011		December 31 2010
Cash and cash equivalents	$	—	$	1
Accounts receivable, net	—		4
Electric utility plant, net	5		5

- Definition

Tabular disclosure of the significant judgments and assumptions made in determining whether a variable interest (as defined) held by the entity requires the variable interest entity (VIE) (as defined) to be consolidated and (or) disclose information about its involvement with the VIE, individually or in aggregate (as applicable); the nature of restrictions, if any, on the consolidated VIE's assets and on the settlement of its liabilities reported by an entity in its statement of financial position, including the carrying amounts of such assets and liabilities; the nature of, and changes in, the risks associated with involvement in the VIE; how involvement with the VIE affects the entity's financial position, financial performance, and cash flows; the lack of recourse if creditors (or beneficial interest holders) of the consolidated VIE have no recourse to the general credit of the primary beneficiary (if applicable); the terms of arrangements, giving consideration to both explicit arrangements and implicit variable interests, if any, that could require the entity to provide financial support to the VIE, including events or circumstances that could expose the entity to a loss; the methodology used by the entity for determining whether or not it is the primary beneficiary of the variable interest entity; the significant factors considered and judgments made in determining that the power to direct the activities of a VIE that most significantly impact the VIE's economic performance are shared (as defined); the carrying amounts and classification of assets and liabilities of the VIE included in the statement of financial position; the entity's maximum exposure to loss, if any, as a result of its involvement with the VIE, including how the maximum exposure is determined and significant sources of the entity's exposure to the VIE; a comparison of the carrying amounts of the assets and liabilities and the entity's maximum exposure to loss; information about any liquidity arrangements, guarantees, and (or) other commitments by third parties that may affect the fair value or risk of the entity's variable interest in the VIE; whether or not the entity has provided financial support or other support (explicitly or implicitly) to the VIE that it was not previously contractually required to provide or whether the entity intends to provide that support, including the type and amount of the support and the primary reasons for providing the support; and supplemental information the entity determines necessary to provide.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 46R
-Paragraph 4
-Subparagraph g
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 46R
-Paragraph 2, 14, 15, 16, 23, 24, 25, 26
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 140
-Paragraph 35
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6970148&loc=d3e5728-111685

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-Publisher FASB
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-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6970148&loc=d3e5747-111685

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Variable Interest Entity
-URI http://asc.fasb.org/extlink&oid=6528138

Reference 8: http://www.xbrl.org/2003/role/presentationRef
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-Name FASB Staff Position (FSP)
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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 167
-Appendix D
-Paragraph 22B

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 167
-Appendix D
-Paragraph 22E

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 167
-Appendix D
-Paragraph 23A

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 167
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-Paragraph 24

Reference 13: http://www.xbrl.org/2003/role/presentationRef
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Reference 14: http://www.xbrl.org/2003/role/presentationRef
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-Topic 810
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-Paragraph 9
-URI http://asc.fasb.org/extlink&oid=6970148&loc=SL6228884-111685

+ Details

Basis of Presentation (Details)	Jun. 30, 2011 shares
Basis of Presentation [Abstract]
NumberofRetailCustomers	824,526

Balance Sheet Components (Details) $ in Millions	3 Months Ended		6 Months Ended
Balance Sheet Components (Details) $ in Millions	Jun. 30, 2011 USD ($)	Jun. 30, 2010 USD ($)	Jun. 30, 2011 USD ($)	Jun. 30, 2010 USD ($)	Dec. 31, 2010 USD ($)	Dec. 31, 2009 USD ($)
Valuation and Qualifying Accounts Disclosure [Line Items]
Preliminary engineering transferred to construction work in progress			$ 7	$ 0
Asset Retirement Obligation Increase related to Boardman plant			23
Credit Facilities - $370 million revolver	$ 370		370
Portion of $370 million credit facility scheduled to terminate in July 2012	10		10
Portion of $370 million credit facility scheduled to terminate in July 2013	360		360
Credit Facility $200 million revolver	200		200
Credit Facility $30 million revolver	$ 30		$ 30
Debt Instrument, Covenant Description			0.65
Ratio of Indebtedness to Net Capital	0.522		0.522
Finite-Lived Intangible Assets, Accumulated Amortization	$ 143		$ 143		$ 133
Allowance for Doubtful Accounts Receivable, Current	5	$ 5	5	5	$ 5	$ 5
Amortization of Intangible Assets	5	$ 4	9	$ 7
Authorized Short-Term Debt	750		750
Line of Credit Facility, Amount Outstanding	126		126
Line of Credit Facility, Remaining Borrowing Capacity	$ 474		$ 474

Balance Sheet Components Allowance for Uncollectible Accounts (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2011	Jun. 30, 2010
Allowance for Uncollectible Accounts
Balance as of begining of period	$ 5	$ 5
Provision, net	3	3
Amounts written off, less recoveries	(3)	(3)
Balance as of end of period	$ 5	$ 5

Balance Sheet Components Electric Utility Plant, Net (Details) - USD ($) $ in Millions	Jun. 30, 2011	Dec. 31, 2010
Property, Plant and Equipment [Line Items]
Electric utility plant	$ 6,458	$ 6,279
Less: accumulated depreciation and amortization	2,352	2,271
Total cost	6,579	6,404
Construction work in progress	121	125
Electric utility plant, net	$ 4,227	$ 4,133

Balance Sheet Components Regulatory Assets and Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2011	Dec. 31, 2010
Current Regulatory Liabilities [Member]
Regulatory liabilities:
Asset retirement removal costs	$ 0	$ 0
Asset retirement obligations	0	0
Power Cost Adjustment Mechanism	0	0
Regulatory treatment of income taxes (SB 408)	8	5
Trojan ISFSI pollution control tax credits	9	18
Other	2	2
Total regulatory liabilities	19	25
Noncurrent Regulatory Liabilities [Member]
Regulatory liabilities:
Asset retirement removal costs	612	588
Asset retirement obligations	34	33
Power Cost Adjustment Mechanism	12	0
Regulatory treatment of income taxes (SB 408)	1	9
Trojan ISFSI pollution control tax credits	5	4
Other	28	23
Total regulatory liabilities	692	657
Regulatory Assets, Current [Member]
Regulatory assets:
Price risk management	153	175
Pension and other postretirement plans	0	0
Deferred income taxes	0	0
Deferred broker settlements	12	24
Renewable energy deferral	12	22
Debt reacquisition costs	0	0
Other	7	0
Total regulatory assets	184	221
Noncurrent Regulatory Assets [Member]
Regulatory assets:
Price risk management	142	185
Pension and other postretirement plans	207	213
Deferred income taxes	91	95
Deferred broker settlements	0	0
Renewable energy deferral	0	0
Debt reacquisition costs	22	23
Other	19	28
Total regulatory assets	$ 481	$ 544

Balance Sheet Components Other Current Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2011	Dec. 31, 2010
Accrued interest payable	$ 26	$ 26
Accrued taxes payable	19	22
Dividends Payable, Current	21	20
Other	8	10
Total other current liabilities	$ 74	$ 78

- Definition

Carrying amount as of the balance sheet date of the unpaid sum of the known and estimated amounts payable to satisfy all currently due domestic and foreign income tax obligations.

+ References + Details

- Definition

Aggregate carrying amount, as of the balance sheet date, of obligations incurred and payable, pertaining to costs that are statutory in nature, are incurred on contractual obligations, or accumulate over time and for which invoices have not yet been received or will not be rendered and of liabilities not separately disclosed in the balance sheet. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer).

+ References + Details

Balance Sheet Components Pension and Other Postretirement Benefits (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2011	Mar. 31, 2010	Jun. 30, 2011	Jun. 30, 2010
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 3	$ 3	$ 6	$ 6
Interest cost	7	7	14	14
Expected return on plan assets	(10)	(10)	(20)	(20)
Amortization of net actuarial gain	2	1	4	2
Net periodic benefit cost	2	1	4	2
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	0	1	1
Interest cost	1	1	2	2
Expected return on plan assets	0	0	0	0
Amortization of net actuarial gain	0	1	0	1
Net periodic benefit cost	1	2	3	4
Non Qualified Benefit Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	0	0	0
Interest cost	0	0	1	1
Expected return on plan assets	0	0	0	0
Amortization of net actuarial gain	0	0	0	0
Net periodic benefit cost	$ 0	$ 0	$ 1	$ 1

- Definition

The net increase or decrease of changes in the value of either the benefit obligation or the plan assets resulting from experience different from that assumed or from a change in an actuarial assumption, or the consequence of a decision to temporarily deviate from the substantive plan.

+ References

+ Details

- Definition

An amount calculated as a basis for determining the extent of delayed recognition of the effects of changes in the fair value of assets. The expected return on plan assets is determined based on the expected long-term rate of return on plan assets and the market-related value of plan assets.

+ References

+ Details

- Definition

The increase in a defined benefit pension plan's projected benefit obligation or a defined benefit postretirement plan's accumulated postretirement benefit obligation due to the passage of time.

+ References + Details

- Definition

The actuarial present value of benefits attributed by the pension benefit formula to services rendered by employees during the period. The portion of the expected postretirement benefit obligation attributed to employee service during the period. The service cost component is a portion of the benefit obligation and is unaffected by the funded status of the plan.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 106
-Paragraph 518
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 87
-Paragraph 264
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
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Reference 4: http://www.xbrl.org/2003/role/presentationRef
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-Section 50
-Paragraph 1
-Subparagraph (a)(1)
-URI http://asc.fasb.org/extlink&oid=6962843&loc=d3e1928-114920

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Service Cost (Component of Net Periodic Pension Cost)
-URI http://asc.fasb.org/extlink&oid=6525008

+ Details

Fair Value of Financial Instruments Financial Assets and Liabilities Recognized at Fair Value (Details) - USD ($) $ in Millions	Jun. 30, 2011	Dec. 31, 2010
Estimate of Fair Value, Fair Value Disclosure [Member]
Nuclear decommissioning trust (1):
Money market funds	$ 14	$ 13
Debt securities:
U.S. treasury securities	8	3
Corporate debt securities	5	6
Mortgage-backed securities	6	7
Municipal securities	2	4
Asset-backed securities	1	1
Equity securities:
Mutual funds	14	17
Common stocks	2	2
Debt securities - mutual funds	3	2
Assets from price risk management activities (1) (3):
Electricity	7	5
Natural gas	3	11
Total	65	71
Liabilities - Liabilities from price risk management activities (1) (3):
Electricity	93	119
Natural gas	213	257
Total	306	376
Fair Value, Inputs, Level 1 [Member]
Nuclear decommissioning trust (1):
Money market funds	0	0
Debt securities:
U.S. treasury securities	8	3
Corporate debt securities	0	0
Mortgage-backed securities	0	0
Municipal securities	0	0
Asset-backed securities	0	0
Equity securities:
Mutual funds	13	16
Common stocks	2	2
Debt securities - mutual funds	3	2
Assets from price risk management activities (1) (3):
Electricity	0	0
Natural gas	0	0
Total	26	23
Liabilities - Liabilities from price risk management activities (1) (3):
Electricity	0	0
Natural gas	0	0
Total	0	0
Fair Value, Inputs, Level 2 [Member]
Nuclear decommissioning trust (1):
Money market funds	14	13
Debt securities:
U.S. treasury securities	0	0
Corporate debt securities	5	6
Mortgage-backed securities	6	7
Municipal securities	2	4
Asset-backed securities	1	1
Equity securities:
Mutual funds	1	1
Common stocks	0	0
Debt securities - mutual funds	0	0
Assets from price risk management activities (1) (3):
Electricity	6	4
Natural gas	3	11
Total	38	47
Liabilities - Liabilities from price risk management activities (1) (3):
Electricity	68	102
Natural gas	110	153
Total	178	255
Fair Value, Inputs, Level 3 [Member]
Nuclear decommissioning trust (1):
Money market funds	0	0
Debt securities:
U.S. treasury securities	0	0
Corporate debt securities	0	0
Mortgage-backed securities	0	0
Municipal securities	0	0
Asset-backed securities	0	0
Equity securities:
Mutual funds	0	0
Common stocks	0	0
Debt securities - mutual funds	0	0
Assets from price risk management activities (1) (3):
Electricity	1	1
Natural gas	0	0
Total	1	1
Liabilities - Liabilities from price risk management activities (1) (3):
Electricity	25	17
Natural gas	103	104
Total	$ 128	$ 121

Fair Value of Financial Instruments Unobservable Input Reconciliation (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2011	Jun. 30, 2010	Jun. 30, 2011	Jun. 30, 2010
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Net liabilities from price risk management activities as of beginning of period	$ 116	$ 221	$ 120	$ 154
Realized and unrealized (gains) and losses, net	10	2	8	59
Purchases, issuances and settlements, net		2		12
Purchases	1		0
Settlements	0		(1)
Net liabilities from price risk management activities as of end of period	$ 127	$ 225	$ 127	$ 225

Fair Value of Financial Instruments Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Jun. 30, 2011	Dec. 31, 2010
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term Debt, Fair Value	$ 1,969	$ 1,968
Long-term Debt	1,798	1,808
Cash Surrender Value, Fair Value Disclosure	$ 23	$ 23

- Definition

This element represents the portion of the balance sheet assertion valued at fair value by the entity whether such amount is presented as a separate caption or as a parenthetical disclosure. Additionally, this element may be used in connection with the fair value disclosures required in the footnote disclosures to the financial statements. The element may be used in both the balance sheet and disclosure in the same submission. This element represents the portion of a balance sheet assertion valued at fair value by the entity whether such amount is presented as a separate caption or as a parenthetical disclosure. Additionally, this element may be used in connection with the fair value disclosures required in the footnote disclosures to the financial statements. The element may be used in both the balance sheet and disclosure in the same submission. This item represents the amount that could be realized under a life insurance contract or contracts owned by the Company as of the date of the statement of financial position. Such Company-owned life insurance policies are commonly known as corporate-owned life insurance (COLI) or bank-owned life insurance (BOLI).

+ References + Details

Price Risk Management Collateral Posted With Counterparties Where Master Netting Arragements Exist (Details) - USD ($) $ in Millions	Jun. 30, 2011	Dec. 31, 2010
Derivative, Collateral, Master Netting Arrangements, Letters of Credit	$ 17	$ 31

Price Risk Management Net volumes related to price risk management activities (Details) - shares shares in Millions	Jun. 30, 2011	Dec. 31, 2010
Commodity contracts:
Electricity	12	9
Natural gas	82	93
Foreign currency	11	7

Price Risk Management Fair values of price risk management assets and liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2011	Dec. 31, 2010
Current Assets, Commodity Contracts:
Electricity	$ 6	$ 4
Natural gas	3	9
Total current derivative assets	9	13
Noncurrent Assets, Commodity Contracts: [Abstract]
Electricity	1	1
Natural gas	0	2
Total noncurrent derivative assets	1	3
Total derivative assets not designated as hedging instruments	10	16
Total derivative assets	10	16
Current Liabilities, Commodity Contracts: [Abstract]
Electricity	56	77
Natural gas	107	111
Total current derivative liabilities	163	188
Noncurrent Liabilities, Commodity Contracts: [Abstract]
Electricity	37	42
Natural gas	106	146
Total noncurrent derivative liabilities	143	188
Total derivative liabilities not designated as hedging instruments	306	376
Total derivative liabilities	$ 306	$ 376

Price Risk Management Net realized and unrealized gains and losses on derivative transactions (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2011	Jun. 30, 2010	Jun. 30, 2011	Jun. 30, 2010
Derivative [Line Items]
Net gain or loss recognized in the statement of income offset by regulatory accounting	$ (10)	$ (25)	$ (35)	$ (159)
Commodity contracts:
Electricity	1	(6)	(31)	(59)
Natural Gas	$ (17)	$ (18)	$ (11)	$ (109)

Price Risk Management Future Year Net Unrealized Gain/Loss Recorded at Balance Sheet Date Expected to Become Realized (Details) - Gain (Loss) on Derivatives [Member] - USD ($) $ in Millions	6 Months Ended	12 Months Ended				42 Months Ended
	Dec. 31, 2011	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014
Commodity contracts:
Electricity	$ 22	$ 0	$ 7	$ 18	$ 39	$ 86
Natural gas	56	1	10	46	97	210
Net unrealized loss	$ 78	$ 1	$ 17	$ 64	$ 136	$ 296

Price Risk Management Derivative Instruments with Credit-Risk-Related Contingent Features (Details) $ in Millions	Jun. 30, 2011 USD ($)
Derivative [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 255
Collateral Already Posted, Aggregate Fair Value	106
Additional Collateral, Aggregate Fair Value	$ 249

Price Risk Management Counterparties Representing 10% or More (Details)	Jun. 30, 2011	Dec. 31, 2010
Assets from price risk management activities:
Counterparty A	24.00%	22.00%
Counterparty B	13.00%	11.00%
Counterparty C	12.00%	23.00%
Counterparty D	10.00%	1.00%
Counterparty E	0.00%	10.00%
Concentration of Risk, Derivative Instruments, Assets	59.00%	67.00%
Liabilities from price risk management activities:
Counterparty C	25.00%	24.00%
Counterparty F	10.00%	9.00%
Counterparty G	9.00%	12.00%
Concentration of Risk, Derivative Instruments, Liabilities	44.00%	45.00%

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2011	Jun. 30, 2010	Jun. 30, 2011	Jun. 30, 2010
Numerator in millions [Abstract]
Net Income (Loss) Attributable to Parent	$ 22	$ 24	$ 91	$ 51
Denominator in thousands [Abstract]
Weighted Average Number of Shares Outstanding, Basic	75,326	75,276	75,322	75,253
Weighted Average Number Diluted Shares Outstanding Adjustment	75	14	47	15
Weighted Average Number of Shares Outstanding, Diluted	75,401	75,290	75,369	75,268
Earnings Per Share [Abstract]
Basic	$ 0.29	$ 0.32	$ 1.21	$ 0.68
Diluted	$ 0.29	$ 0.32	$ 1.21	$ 0.68

- Definition

The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 128
-Paragraph 36, 37, 38
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Article 5
-Section 03
-Paragraph 20

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 04
-Article 7
-Paragraph 18

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 04
-Paragraph 21
-Article 9

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 225
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03.21)
-URI http://asc.fasb.org/extlink&oid=6880815&loc=d3e20235-122688

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 260
-SubTopic 10
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6920599&loc=d3e1252-109256

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 260
-SubTopic 10
-Section 55
-Paragraph 52
-URI http://asc.fasb.org/extlink&oid=6945512&loc=d3e4984-109258

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 260
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6371337&loc=d3e3550-109257

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 225
-Section S99
-Paragraph 1
-Subparagraph (SX 210.9-04.23)
-URI http://asc.fasb.org/extlink&oid=6879574&loc=d3e536633-122882

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 225
-Section S99
-Paragraph 1
-Subparagraph (SX 210.7-04.19)
-URI http://asc.fasb.org/extlink&oid=6879464&loc=d3e573970-122913

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number 07-4
-Paragraph 4
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

- Definition

The amount of net income (loss) for the period available to each share of common stock or common unit outstanding during the reporting period and to each share or unit that would have been outstanding assuming the issuance of common shares or units for all dilutive potential common shares or units outstanding during the reporting period.

+ References + Details

- Definition

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number 87-21
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 38
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 130
-Paragraph 10, 15
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 95
-Paragraph 28, 29, 30
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Article 5
-Section 03
-Paragraph 19

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 04
-Paragraph 20
-Article 9

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 230
-SubTopic 10
-Section 45
-Paragraph 28
-URI http://asc.fasb.org/extlink&oid=6943989&loc=d3e3602-108585

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Net Income
-URI http://asc.fasb.org/extlink&oid=6518256

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Other Comprehensive Income
-URI http://asc.fasb.org/extlink&oid=6519514

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 260
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6371337&loc=d3e3550-109257

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 225
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03.18)
-URI http://asc.fasb.org/extlink&oid=6880815&loc=d3e20235-122688

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 225
-Section S99
-Paragraph 1
-Subparagraph (SX 210.7-04.19)
-URI http://asc.fasb.org/extlink&oid=6879464&loc=d3e573970-122913

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e565-108580

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 225
-Section S99
-Paragraph 1
-Subparagraph (SX 210.7-04.22)
-URI http://asc.fasb.org/extlink&oid=6879464&loc=d3e573970-122913

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 38
-Subparagraph d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph A7
-Appendix A

+ Details

- Definition

The average number of shares or units issued and outstanding that are used in calculating diluted EPS or earnings per unit (EPU), determined based on the timing of issuance of shares or units in the period.

+ References + Details

- Definition

Number of [basic] shares or units, after adjustment for contingently issuable shares or units and other shares or units not deemed outstanding, determined by relating the portion of time within a reporting period that common shares or units have been outstanding to the total time in that period.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 128
-Paragraph 171
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 128
-Paragraph 40
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 128
-Paragraph 8
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 260
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6371337&loc=d3e3550-109257

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 260
-SubTopic 10
-Section 45
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=6920599&loc=d3e1448-109256

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Weighted-Average Number of Common Shares Outstanding
-URI http://asc.fasb.org/extlink&oid=6528421

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number 07-4
-Paragraph 4
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Equity (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
Equity (Details) - USD ($) $ in Millions	Jun. 30, 2011	Jun. 30, 2010	Jun. 30, 2011	Jun. 30, 2010	Mar. 31, 2011
Common Stock, Shares, Outstanding beginning of period			75,316,419
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest			$ 1,599
Net Income (Loss) Attributable to Parent	$ 22	$ 24	$ 91	$ 51
Common Stock, Shares, Outstanding end of period	75,341,104		75,341,104
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 1,648		$ 1,648
Common Stock, Capital Shares Reserved for Future Issuance					2,500,000
Common Stock [Member]
Common Stock, Shares, Outstanding beginning of period			75,316,419	75,210,580
Vesting of Restricted and Performance Stock Units, Shares			12,104	69,561
Stock Issued During Period, Shares, Employee Stock Purchase Plans			11,320	14,846
Shares Issued During Period, Dividend Reinvestment and Direct Stock Purchase Plan			1,261
Common Stock, Shares, Outstanding end of period	75,341,104	75,294,987	75,341,104	75,294,987
Common Stock Including Additional Paid in Capital [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest			$ 831	$ 829
Vesting of Restricted and Performance Stock Units, Value			0	0
Stock Issued During Period, Value, Employee Stock Purchase Plan			0	0
Stock Issued During Peirod, Value, Dividend Reinvestment and Direct Stock Purchase Plan			0
Share-based Compensation			1	1
Dividends, Common Stock			0	0
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders			0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 832	$ 830	832	830
Accumulated Other Comprehensive Income (Loss) [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest			(5)	(6)
Vesting of Restricted and Performance Stock Units, Value			0	0
Stock Issued During Period, Value, Employee Stock Purchase Plan			0	0
Share-based Compensation			0	0
Dividends, Common Stock			0	0
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders			0
Other Comprehensive Income (Loss), Net of Tax				1
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	(5)	(5)	(5)	(5)
Retained Earnings [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest			766	719
Vesting of Restricted and Performance Stock Units, Value			0	0
Stock Issued During Period, Value, Employee Stock Purchase Plan			0	0
Share-based Compensation			0	0
Dividends, Common Stock			(39)	(39)
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders			0
Net Income (Loss) Attributable to Parent			91	51
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	818	731	818	731
Noncontrolling Interest [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest			7	1
Vesting of Restricted and Performance Stock Units, Value			0	0
Stock Issued During Period, Value, Employee Stock Purchase Plan			0	0
Share-based Compensation			0	0
Dividends, Common Stock			0	0
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders			(4)
Net Income (Loss) Attributable to Noncontrolling Interest			0	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 3	$ 1	$ 3	$ 1

Comprehensive Income (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
Comprehensive Income (Details) - USD ($) $ in Millions	Jun. 30, 2011	Jun. 30, 2010	Jun. 30, 2011	Jun. 30, 2010
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ 22	$ 24	$ 91	$ 51
Other comprehensive income - Change in compensation retirement benefits liability and amortization, net of taxes	0	0	0	1
Comprehensive income and Comprehensive income attributable to Portland General Electric Company	$ 22	$ 24	$ 91	$ 52

- Definition

The change in equity [net assets] of a business enterprise during a period from transactions and other events and circumstances from non-owner sources which are attributable to the reporting entity. It includes all changes in equity during a period except those resulting from investments by owners and distributions to owners, but excludes any and all transactions which are directly or indirectly attributable to that ownership interest in subsidiary equity which is not attributable to the parent.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 8, 9, 10, 11, 12, 13, 14
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 30
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph A5
-Appendix A

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e557-108580

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Net Income
-URI http://asc.fasb.org/extlink&oid=6518256

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Other Comprehensive Income
-URI http://asc.fasb.org/extlink&oid=6519514

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+ Details

- Definition

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

+ References

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+ Details

Contingencies (Details) - USD ($)	3 Months Ended	12 Months Ended
Contingencies (Details) - USD ($)	Jun. 30, 2011	Dec. 31, 2008	Dec. 31, 2005	Sep. 30, 2010	Sep. 30, 2008	Dec. 31, 2003
Loss Contingencies [Line Items]
Customer refund for Trojan Investment, net of Interest					$ 15,400,000
Interest Rate Applied to Trojan Refund					9.60%
Refund to customers for Trojan Investment including interest					$ 33,100,000
Class action damages sought						$ 260,000,000
Annual charges for state and federal income taxes			$ 92,600,000
Deferred Liability Under Sb 408 For 2005			$ 26,500,000
Daily Penalty Sought Per Violation Before March 15 2004					27,500
Daily Penalty Sought Per Violation After March 15 2004					32,500
Payable for environmental projects	$ 2,500,000
Payable for legal expenses	1,000,000
Settlement Expenses For Sierra Club Claim	$ 2,000,000
Total penalties and damages asserted in Sierra Club Lawsuit					$ 60,000,000
Maximum civil penalties the EPA is authorized to impose under the CAA for violations of the NSPS				$ 25,000
Maximum civil penalties the EPA is authorized to impose under the CAA for violations of the NSPS - upper range				$ 37,500
Repayments of Pollution Control Bond		$ 5,800,000

Variable Interest Entities (Details) - USD ($) $ in Millions	Jun. 30, 2011	Dec. 31, 2010
Cash and cash equivalents	$ 0	$ 1
Accounts receivable, net	0	4
Electric utility plant, net	$ 5	$ 5