Chugach Electric Association 10-K 20 Mar 14 2013 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013
Document And Entity Information [Abstract]	'
Document Type	'10-K
Amendment Flag	'false
Document Period End Date	31-Dec-13
Document Fiscal Year Focus	'2013
Document Fiscal Period Focus	'FY
Entity Registrant Name	'CHUGACH ELECTRIC ASSOCIATION INC
Entity Central Index Key	'0000878004
Current Fiscal Year End Date	'--12-31
Entity Filer Category	'Non-accelerated Filer
Entity Common Stock, Shares Outstanding	0
Entity Public Float	$0
Entity Well-known Seasoned Issuer	'No
Entity Current Reporting Status	'No
Entity Voluntary Filers	'Yes

Balance_Sheets

Balance Sheets (USD $)	Dec. 31, 2013		Dec. 31, 2012
Assets	'		'
Electric Plant in service	$1,135,356,956		$891,781,509
Construction work in progress	28,674,163	[1]	263,459,794	[1]
Total utility plant	1,164,031,119		1,155,241,303
Less accumulated depreciation	-464,880,322		-449,266,075
Net utility plant	699,150,797		705,975,228
Other property and investments, at cost:	'		'
Nonutility property	76,889		84,735
Investments in associated organizations	10,204,193		10,552,683
Special funds	536,546		570,027
Total other property and investments	10,817,628		11,207,445
Current assets:	'		'
Cash and cash equivalents, including repurchase agreements of $100 in 2013 and 2012	4,347,163		14,047,469
Special deposits	158,265		153,233
Restricted cash equivalents	3,706,832		1,953,085
Marketable securities	10,308,533		10,158,016
Accounts receivable, less provision for doubtful accounts of $541,747 in 2013 and $490,413 in 2012	44,633,981		46,650,901
Materials and supplies	25,856,395		32,867,971
Fuel stock	13,029,848		9,466,767
Prepayments	1,863,407		2,156,862
Other current assets	320,658		252,146
Total current assets	104,225,082		117,706,450
Deferred charges, net	23,990,531		27,712,243
Total assets	838,184,038		862,601,366
Equities and margins:	'		'
Memberships	1,600,058		1,559,344
Patronage capital	162,749,889		153,832,674
Other	11,445,918		11,372,355
Total equities and margins	175,795,865		166,764,373
Long-term obligations, excluding current installments:	'		'
Bonds payable	469,499,999		491,916,666
National Bank for Cooperatives note payable	27,414,275		29,680,420
Total long-term obligations	496,914,274		521,597,086
Current liabilities:	'		'
Current installments of long-term obligations	24,682,812		24,493,022
Commercial paper	30,000,000		11,500,000
Accounts payable	11,461,303		16,488,323
Consumer deposits	4,851,558		4,279,901
Fuel cost over-recovery	1,635,677		13,710,049
Accrued interest	6,512,860		6,807,207
Salaries, wages and benefits	8,967,140		8,369,203
Fuel	14,834,585		20,868,078
Other current liabilities	5,143,905		4,559,981
Total current liabilities	108,089,840		111,075,764
Deferred compensation	536,546		570,027
Deferred liabilities	1,776,826		1,769,172
Patronage capital payable	7,931,295		6,858,367
Cost of removal obligation	47,139,392		44,628,315
Deferred proceeds on sale of asset	0		9,338,262
Total liabilities, equities and margins	$838,184,038		$862,601,366
[1]	The amount associated with the construction of SPP included in construction work in progress was $245.5 million at December 31, 2012.

Balance_Sheets_Parenthetical

Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Balance Sheets [Abstract]	'	'
Cash and cash equivalent, repurchase agreements	$100	$100
Provision for doubtful accounts	$541,747	$490,413

Statements_Of_Operations

Statements Of Operations (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statements Of Operations [Abstract]	'	'	'
Operating revenues	$305,308,427	$266,971,468	$283,618,369
Operating expenses:	'	'	'
Fuel	136,610,262	125,836,659	139,179,413
Production	21,911,324	16,739,931	16,853,232
Purchased power	27,836,680	22,104,687	25,861,814
Transmission	6,624,836	5,802,009	6,809,401
Distribution	13,225,242	15,822,104	13,387,477
Consumer accounts	6,014,888	6,013,419	5,465,315
Administrative, general and other	23,131,149	23,519,246	22,169,039
Depreciation and amortization	43,384,116	32,356,900	32,616,175
Total operating expenses	278,738,497	248,194,955	262,341,866
Interest expense:	'	'	'
Long-term debt and other	24,691,582	24,085,371	18,681,680
Charged to construction	-1,310,110	-9,682,440	-1,934,703
Interest expense, net	23,381,472	14,402,931	16,746,977
Net operating margins	3,188,458	4,373,582	4,529,526
Nonoperating margins:	'	'	'
Interest income	686,460	447,434	297,983
Allowance for funds used during construction	141,014	258,301	159,916
Gain of sale of asset	6,436,992	0	0
Capital credits, patronage dividends and other	91,119	446,190	585,837
Total nonoperating margins	7,355,585	1,151,925	1,043,736
Assignable margins	$10,544,043	$5,525,507	$5,573,262

Statements_Of_Changes_In_Equit

Statements Of Changes In Equities And Margins (USD $)	3 Months Ended				12 Months Ended
	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Balance	'	$166,764,373	'	$161,231,426	$166,764,373	$161,231,426	$161,842,284
Assignable margins	8,215,331	4,841,576	3,373,971	3,423,068	10,544,043	5,525,507	5,573,262
Retirement/net transfer of capital credits	'	'	'	'	-1,626,828	-48,079	-6,761,968
Unclaimed capital credit retirements	'	'	'	'	-21,456	-12,949	367,277
Memberships and donations received	'	'	'	'	135,733	68,468	210,571
Balance	175,795,865	'	166,764,373	'	175,795,865	166,764,373	161,231,426
Memberships [Member]	'	'	'	'	'	'	'
Balance	'	1,559,344	'	1,517,488	1,559,344	1,517,488	1,474,869
Assignable margins	'	'	'	'	0	0	0
Retirement/net transfer of capital credits	'	'	'	'	0	0	0
Unclaimed capital credit retirements	'	'	'	'	0	0	0
Memberships and donations received	'	'	'	'	40,714	41,856	42,619
Balance	1,600,058	'	1,559,344	'	1,600,058	1,559,344	1,517,488
Other Equities And Margins [Member]	'	'	'	'	'	'	'
Balance	'	11,372,355	'	11,358,692	11,372,355	11,358,692	10,823,463
Assignable margins	'	'	'	'	0	0	0
Retirement/net transfer of capital credits	'	'	'	'	0	0	0
Unclaimed capital credit retirements	'	'	'	'	-21,456	-12,949	367,277
Memberships and donations received	'	'	'	'	95,019	26,612	167,952
Balance	11,445,918	'	11,372,355	'	11,445,918	11,372,355	11,358,692
Patronage Capital [Member]	'	'	'	'	'	'	'
Balance	'	153,832,674	'	148,355,246	153,832,674	148,355,246	149,543,952
Assignable margins	'	'	'	'	10,544,043	5,525,507	5,573,262
Retirement/net transfer of capital credits	'	'	'	'	-1,626,828	-48,079	-6,761,968
Unclaimed capital credit retirements	'	'	'	'	0	0	0
Memberships and donations received	'	'	'	'	0	0	0
Balance	$162,749,889	'	$153,832,674	'	$162,749,889	$153,832,674	$148,355,246

Statements_Of_Cash_Flows

Statements Of Cash Flows (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities:	'	'	'
Assignable margins	$10,544,043	$5,525,507	$5,573,262
Adjustments to reconcile assignable margins to net cash provided by operating activities:	'	'	'
Depreciation	43,384,116	32,356,900	32,616,175
Amortization and depreciation cleared to operating expense	5,912,254	5,882,580	5,472,557
Allowance for funds used during construction	-141,014	-258,301	-159,916
Write off of inventory, deferred charges and projects	430,453	991,871	851,756
Gain of sale of Bernice Lake Power Plant	-6,436,992	0	0
Other	240,836	-135,739	-93,834
(Increase) decrease in assets:	'	'	'
Accounts receivable, net	4,823,879	-4,276,906	-7,128,876
Fuel cost under-recovery	0	1,213,484	1,158,147
Materials and supplies	-907,942	-189,092	2,563,223
Fuel stock	-3,563,081	-9,466,767	0
Prepayments	293,455	-245,073	13,635
Other assets	-1,827,291	27,937	-2,049,082
Deferred charges	-317,070	-4,335,252	-6,358,154
Increase (decrease) in liabilities:	'	'	'
Accounts payable	1,775,412	1,454,677	1,891,089
Consumer deposits	571,657	330,849	-1,276,677
Fuel cost over-recovery	-12,074,372	13,710,049	0
Accrued interest	-294,347	-36,266	793,942
Salaries, wages and benefits	597,937	771,512	863,849
Fuel	-6,033,493	-3,531,079	2,829,619
Other current liabilities	2,901,022	3,094,139	3,011,319
Deferred liabilities	3,399	120,204	239,761
Net cash (used in) provided by operating activities	39,882,861	43,005,234	40,811,795
Cash flows from investing activities:	'	'	'
Proceeds on sale of Bernice Lake Power Plant	0	0	9,537,530
Investment in associated organizations	424,484	663,697	1,153,470
Investment in restricted cash equivalents	0	0	-270,000,000
Investment in marketable securities	-327,175	-10,096,304	0
Proceeds from restricted cash equivalents	0	120,000,000	150,000,000
Extension and replacement of plant	-44,144,184	-109,180,413	-123,679,854
Net cash (used in) provided by investing activities	-44,046,875	1,386,980	-232,988,854
Cash flows from financing activities:	'	'	'
Payments for debt issue costs	0	-1,850,199	-1,949,027
Proceeds from short-term obligations	45,500,000	24,500,000	76,500,000
Proceeds from long-term obligations	0	250,000,000	275,000,000
Repayments of short-term obligations	-27,000,000	-188,000,000	0
Repayments of long-term obligations	-24,493,022	-133,360,210	-152,851,500
Memberships and donations received	114,277	55,519	189,385
Retirement of patronage capital and estate payments	-156,565	-48,079	-309,188
Net receipts on consumer advances for construction	499,018	1,240,106	644,794
Net cash (used in) provided by financing activities	-5,536,292	-47,462,863	197,224,464
Net change in cash and cash equivalents	-9,700,306	-3,070,649	5,047,405
Cash and cash equivalents at beginning of period	14,047,469	17,118,118	12,070,713
Cash and cash equivalents at end of period	4,347,163	14,047,469	17,118,118
Supplemental disclosure of non-cash investing and financing activities:	'	'	'
Retirement of plant	24,095,596	10,405,777	11,317,319
Cost of removal obligation	2,511,077	3,148,135	3,160,851
Extension and replacement of plant included in accounts payable	3,817,788	10,620,219	15,561,199
Supplemental disclosure of cash flow information - interest expense paid, net of amounts capitalized	$21,839,391	$13,092,576	$12,590,296

Description_Of_Business

Description Of Business	12 Months Ended
	Dec. 31, 2013
Description Of Business [Abstract]	'
Description Of Business	'
	(1)    Description of Business
	Chugach Electric Association, Inc. (Chugach) is the largest electric utility in Alaska.  Chugach is engaged in the generation, transmission and distribution of electricity to directly serve retail customers in the Anchorage and upper Kenai Peninsula areas.  Through an interconnected regional electrical system, Chugach's power flows throughout Alaska's Railbelt, a 400-mile-long area stretching from the coastline of the southern Kenai Peninsula to the interior of the state, including Alaska's largest cities, Anchorage and Fairbanks.
	Chugach also supplies much of the power requirements of two wholesale customers, Matanuska Electric Association, Inc. (MEA) and the City of Seward (Seward).  We provided much of the power requirements of Homer Electric Association, Inc. (HEA) through their contract expiration date of December 31, 2013.  We sell available generation in excess of our own needs to produce electric energy for sale to Golden Valley Electric Association, Inc. (GVEA).  In addition, on a periodic basis, we provide electricity to Anchorage Municipal Light & Power (ML&P).  Chugach’s retail and wholesale members are the consumers of the electricity sold.
	Chugach was organized as an Alaska electric cooperative in 1948 and operates on a not‑for‑profit basis and, accordingly, seeks only to generate revenues sufficient to pay operating and maintenance costs, the cost of purchased power, capital expenditures, depreciation, and principal and interest on all indebtedness and to provide for reserves.  Chugach is subject to the regulatory authority of the Regulatory Commission of Alaska (RCA).

Significant_Accounting_Policie

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Significant Accounting Policies [Abstract]	'
Significant Accounting Policies	'
	(2)    Significant Accounting Policies
	a. Management Estimates
	In preparing the financial statements in conformity with United States generally accepted accounting principles (GAAP), the management of Chugach is required to make estimates and assumptions relating to the reporting of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the balance sheet and revenues and expenses for the reporting period.  Estimates include allowance for doubtful accounts, workers compensation, deferred charges and credits, unbilled revenue, the estimated useful life of utility plant and the cost of removal obligation.  Actual results could differ from those estimates.
	b. Regulation
	The accounting records of Chugach conform to the Uniform System of Accounts as prescribed by the Federal Energy Regulatory Commission (FERC).  Chugach meets the criteria, and accordingly, follows the accounting and reporting requirements of Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 980, “Topic 980 - Regulated Operations.”  FASB ASC 980 provides for the recognition of regulatory assets and liabilities as allowed by regulators for costs or credits that are reflected in current rates or are considered probable of being included in future rates.  Our regulated rates are established to recover all of our specific costs of providing electric service.  In each rate filing, rates are set at levels to recover all of our specific allowable costs and those rates are then collected from our retail and wholesale customers.  The regulatory assets or liabilities are then reduced as the cost or credit is reflected in earnings and our rates, see Note (2j) – “Deferred Charges and Credits.”
	(2)    Significant Accounting Policies (continued)
	c. Utility Plant and Depreciation
	Additions to electric plant in service are recorded at original cost of contracted services, direct labor and materials, indirect overhead charges and capitalized interest.  For property replaced or retired, the book value of the property, less salvage, is charged to accumulated depreciation.  The removal cost is charged to cost of removal obligation.  Renewals and betterments are capitalized, while maintenance and repairs are normally charged to expense as incurred.
	In accordance with FASB ASC 360, “Topic 360 – Property, Plant, and Equipment,” certain asset groups are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset group may not be recoverable in rates.  Recoverability of asset groups to be held and used is measured by a comparison of the carrying amount of an asset group to estimated undiscounted future cash flows expected to be generated by the asset group.  If the carrying amount of an asset group exceeds its estimated future cash flows, an impairment charge is recognized by the amount by which the carrying amount of the asset group exceeds the fair value of the asset.
	Depreciation and amortization rates have been applied on a straight‑line basis and at December 31, 2013 are as follows:
	Annual Depreciation Rate Ranges
	Steam production plant	4.81%	-	7.04%
	Hydraulic production plant	1.06%	-	3.00%
	Other production plant	3.98%	-	10.15%
	Transmission plant	1.58%	-	7.86%
	Distribution plant	2.17%	-	9.63%
	General plant	1.57%	-	20.00%
	Other	2.75%	-	2.75%
	Southcentral Power Project (SPP) steam production plant	3.09%	-	3.46%
	SPP other production plant	3.15%	-	3.84%
	On November 1, 2010, the RCA approved revised depreciation rates effective November 1, 2010 in Docket U-09-097.  Chugach’s depreciation rates include a provision for cost of removal.
	Chugach records a separate liability for the estimated obligation related to the cost of removal.
	On August 31, 2012, in Docket U-12-009, the RCA approved SPP depreciation rates effective February 1, 2013, the date the SPP plant was placed in service.
	(2)    Significant Accounting Policies (continued)
	d. Capitalized Interest
	Allowance for funds used during construction (AFUDC) and interest charged to construction ‑ credit (IDC) are the estimated costs of the funds used during the period of construction from both equity and borrowed funds.  AFUDC and IDC are applied to specific projects during construction.  AFUDC and IDC calculations use the net cost of borrowed funds when used and is recovered through RCA approved rates as utility plant is depreciated.  For all projects excluding SPP, Chugach capitalized such funds at the weighted average rate (adjusted monthly) of 3.7 percent during 2013, 4.0 percent during 2012 and 4.1 percent during 2011.  For SPP, Chugach capitalized actual interest expense and related fees associated with its construction.
	e. Investments in Associated Organizations
	The loan agreements with CoBank, ACB (CoBank) and National Rural Utilities Cooperative Finance Corporation (NRUCFC) requires as a condition of the extension of credit, that an equity ownership position be established by all borrowers.  Chugach’s equity ownership in these organizations is less than 1 percent.  These investments are non-marketable and accounted for at cost.  Management evaluates these investments annually for impairment.  No impairment was recorded during 2013, 2012 and 2011.
	f. Fair Value of Financial Instruments
	FASB ASC 825, “Topic 825 – Financial Instruments,” requires disclosure of the fair value of certain on and off balance sheet financial instruments for which it is practicable to estimate that value.  The following methods are used to estimate the fair value of financial instruments:
	Cash and cash equivalents ‑ the carrying amount approximates fair value because of the short maturity of those instruments.
	Consumer deposits ‑ the carrying amount approximates fair value because of the short refunding term.
	Long‑term obligations ‑ the fair value is estimated based on the quoted market price for same or
	similar issues (see note 11).
	Restricted cash – the carrying amount approximates fair value because of the short maturity of those instruments.
	Repurchase agreement – the carrying amount approximates fair value because of the short maturity of those instruments.
	(2)    Significant Accounting Policies (continued)
	g. Cash and Cash Equivalents / Restricted Cash Equivalents
	For purposes of the statement of cash flows, Chugach considers all highly liquid instruments with a maturity of three months or less upon acquisition by Chugach to be cash equivalents.  In November of 2011, Chugach opened a concentration account with First National Bank Alaska (FNBA).  There is no rate of return or fees on this account.  On December 30, 2011, Chugach opened a money market account with UBS Financial Services, Inc. (UBS) with an initial deposit of $10.0 million, which was subsequently invested in marketable securities in September of 2012.  Chugach also maintains an Overnight Repurchase Agreement with FNBA, however, in November of 2011 this account was placed into an inactive status.  The concentration account had an average balance of $6,262,978 and $8,942,631 for the years ended December 31, 2013 and 2012, respectively.
	On January 12, 2012, Chugach opened a money market account with KeyBank with the balance of proceeds from the 2012 Series A bond purchase, after repaying the outstanding balance of commercial paper.  Chugach’s initial deposit was $69.0 million.  Chugach used the proceeds primarily to fund capital expenditures associated with SPP and closed the account in February of 2013.
	Restricted cash equivalents include funds on deposit for future workers compensation claims and interim rates collected from customers and escrowed as required by the RCA.
	h. Accounts Receivable
	Trade accounts receivable are recorded at the invoiced amount.  The allowance for doubtful accounts is management’s best estimate of the amount of probable credit losses in existing accounts receivable.  Chugach determines the allowance based on its historical write-off experience and current economic conditions.  Chugach reviews its allowance for doubtful accounts monthly.  Past due balances over 90 days in a specified amount are reviewed individually for collectability.  All other balances are reviewed in aggregate.  Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote.  Chugach does not have any off–balance-sheet credit exposure related to its customers. Included in accounts receivable are invoiced amounts to ML&P for their proportionate share of current SPP costs, which amounted to $1.8 and $3.0 million in 2013 and 2012, respectively.  In addition, accounts receivable includes invoiced amounts for grants to support the construction of facilities to divert water and safely transmit electricity, which amounted to $2.8 million in 2013 and $4.0 million in 2012.
	i. Materials and Supplies
	Materials and supplies are stated at average cost.
	(2)    Significant Accounting Policies (continued)
	j. Deferred Charges and Credits
	In accordance with FASB ASC 980, Chugach’s financial statements reflect regulatory assets and liabilities.  Continued accounting under FASB ASC 980, requires that certain criteria be met. We capitalize all or part of costs that would otherwise be charged to expense if it is probable that future revenue in an amount at least equal to the capitalized cost will result from inclusion of that cost in allowable costs for ratemaking purposes and future revenue will be provided to permit recovery of the previously incurred cost.  Management believes Chugach’s operations currently satisfy these criteria.
	Chugach regulatory asset recoveries are embedded in base rates approved by the RCA.  Specific costs incurred and recorded as Regulatory Assets, including the amortization period for recovery, are approved by the RCA either in standard Simplified Rate Filings (SRF), general rate case filings or specified independent requests.  The rates approved related to the regulatory assets are matched to the amortization of actual expenses recognized. The regulatory assets are amortized and collected through rates over differing periods depending upon the period of benefit as established by the RCA.  Deferred credits, primarily representing regulatory liabilities, are amortized to operating expense over the period required for ratemaking purposes.  It also includes refundable contributions in aid of construction, which are credited to the associated cost of construction of property units.  Refundable contributions in aid of construction are held in deferred credits pending their return or other disposition.  If events or circumstances should change so the criteria are not met, the write off of regulatory assets and liabilities could have a material effect on Chugach’s financial position or results of operations.
	k. Patronage Capital
	Revenues in excess of current period costs (net operating margins and nonoperating margins) in any year are designated on Chugach's statement of revenues and expenses as assignable margins. These excess amounts (i.e. assignable margins) are considered capital furnished by the members, and are credited to their accounts and held by Chugach until such future time as they are retired and returned without interest at the discretion of the Board of Directors (Board).  Retained assignable margins are designated on Chugach's balance sheet as patronage capital.  This patronage capital constitutes the principal equity of Chugach.  The Board may also approve the return of capital to former members and estates who request early retirements at discounted rates under a discounted capital credits retirement plan authorized by the Board in September of 2002.
	In 2007, Chugach entered into an agreement with HEA to return all of its patronage capital within five years after expiration of its power sales agreement, which is December 31, 2013.  This patronage capital retirement was related to a settlement agreement associated with the 2005 Test Year General Rate Case (Docket U-06-134).  The RCA accepted the parties’ settlement agreement on August 9, 2007.  HEA’s patronage capital is classified as patronage capital payable and was $7.9 million at December 31, 2013.
	(2)    Significant Accounting Policies (continued)
	l. Operating Revenues
	Revenues are recognized upon delivery of electricity.  Operating revenues are based on billing rates authorized by the RCA, which are applied to customers' usage of electricity.  Chugach’s rates are established, in part, on test period sales levels that reflect actual operating results.  Chugach calculates unbilled revenue at the end of each month to ensure the recognition of a calendar year’s revenue.  Chugach accrued $9,274,135 and $8,548,660 of unbilled retail revenue at December 31, 2013 and 2012, respectively. Wholesale revenue is recorded from metered locations on a calendar month basis, so no estimation is required.  Chugach's tariffs include provisions for the recovery of gas costs according to gas supply contracts, as well as purchased power costs.
	m. Fuel and Purchased Power Costs Recovery
	Expenses associated with electric services include fuel used to generate electricity and power purchased from others.  Chugach is authorized by the RCA to recover fuel and purchased power costs through the fuel and purchased power adjustment process, which is adjusted quarterly to reflect increases and decreases of such costs.  We recognize differences between projected recoverable fuel costs and amounts actually recovered through rates.  The fuel cost under/over recovery on our Balance Sheet represents the net accumulation of any under- or over-collection of fuel and purchase power costs.  Fuel cost under-recovery will appear as an asset on our Balance Sheet and will be collected from our members in subsequent periods.  Conversely, fuel cost over-recovery will appear as a liability on our Balance Sheet and will be refunded to our members in subsequent periods.  Fuel costs were over-recovered by $1,635,677 in 2013 and over-recovered by $13,710,049 in 2012.  Total fuel and purchased power costs in 2013, 2012, and 2011 were $164,446,942, $147,941,346, and $165,041,227, respectively.
	n. Environmental Remediation Costs
	Chugach accrues for losses and establishes a liability associated with environmental remediation obligations when such losses are probable and can be reasonably estimated.  Such accruals are adjusted as further information develops or circumstances change.   Estimates of future costs for environmental remediation obligations are not discounted to their present value. However, various remediation costs may be recoverable through rates and accounted for as a regulatory
	asset.
	o. Income Taxes
	Chugach is exempt from federal income taxes under the provisions of Section 501(c)(12) of the Internal Revenue Code and for the years ended December 31, 2013, 2012 and 2011 was in compliance with that provision.  In addition, as described in “Note (15) - Commitments and Contingencies,” Chugach collects sales tax and is assessed gross receipts and excise taxes which are presented on a net basis in accordance with FASB ASC 605-45-50, “Topic 605 - Revenue Recognition – Subtopic 45 - Principal Agent Considerations – Section 50 - Disclosure.”
	(2)    Significant Accounting Policies (continued)
o. Income Taxes (continued)
Chugach applies a more-likely-than-not recognition threshold for all tax uncertainties.  FASB ASC 740, “Topic 740 – Income Taxes,” only allows the recognition of those tax benefits that have a greater than 50 percent likelihood of being sustained upon examination by the taxing authorities.  Chugach’s management reviewed Chugach’s tax positions and determined there were no outstanding, or retroactive tax positions, that were not highly certain of being sustained upon examination by the taxing authorities.
Management has concluded that there are no significant uncertain tax positions requiring recognition in its financial statements for all periods presented.  Chugach’s evaluation was performed for the tax periods ended December 31, 2010 through December 31, 2013 for United States Federal Income Tax, the tax years which remain subject to examination by major tax jurisdictions as of December 31, 2013.
p. Consumer deposits
Consumer deposits are the amounts certain customers are required to deposit to receive electric service.  Consumer deposits for the years ended December 31, 2013 and 2012, totaled $2.5 million and $2.4 million, respectively.  Consumer deposits also represent customer credit balances as a result of prepaid accounts.  Credit balances for the years ended December 31, 2013 and 2012 totaled $2.4 million and $1.9 million, respectively.
q. Grants
Chugach has received federal and state grants to offset storm related expenditures and to support the construction of facilities to transport fuel, divert water and safely transmit electricity to its consumers.  Grant proceeds used to construct or acquire equipment are offset against the carrying amount of the related assets while grant proceeds for storm related expenditures are offset against the actual expense incurred, which totaled $17.4 million and $30.5 million in 2013 and 2012, respectively.  The assets constructed from grant awards may not be sold, or used as collateral for any reason.
r. Fuel Stock
Fuel Stock is the weighted average cost of fuel injected into the Cook Inlet Natural Gas Storage Alaska (CINGSA), which began service in the second quarter of 2012.  Chugach’s fuel balance in storage for the years ended December 31, 2013 and 2012 amounted to $13.0 million and $9.5 million, respectively.
s. Marketable Securities
In September of 2012, Chugach implemented a bond and equity investment portfolio.  Chugach’s initial investment was $10.0 million.  The investments are classified as marketable securities, reported at fair value with gains and losses included in earnings.  At December 31, 2013 and 2012, the carrying amount and fair value was $10.3 million and $10.1 million, respectively.
(2)    Significant Accounting Policies (continued)
t. Reclassifications
For the year ended December 31, 2013, Chugach recorded the following reclassification for the year ended December 31, 2012:
A reclassification representing the expected future cost of removal of our regulated assets previously included as an increase in accumulated depreciation and now included as an increase in cost of removal obligations. The impact of the reclassification was to decrease accumulated depreciation and increase cost of removal obligations by $44.6 million in 2012.

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncements	12 Months Ended
	Dec. 31, 2013
Recent Accounting Pronouncements [Abstract]	'
Recent Accounting Pronouncements	'
	(3)    Recent Accounting Pronouncements
	ASC Update 2013-06 “Not-for-Profit Entities (Topic 958): Services Received from Personnel of an Affiliate (a consensus of the Emerging Issues Task Force)”
	In April of 2013, the FASB issued ASC Update 2013-06, “Not-for-Profit Entities (Topic 958): Services Received from Personnel of an Affiliate (a consensus of the FASB Emerging Issues Task Force)” (ASC Update 2013-06).  ASC Update 2013-06 provides guidance for recognizing and measuring services received from personnel of an affiliate.  This update is effective prospectively for fiscal years beginning after June 15, 2014.  Chugach will begin application of ASC 2013-06 on January 1, 2015.  Adoption is not expected to have any incremental effect on results of operations, financial position, and cash flows.
	ASC Update 2013-04 “Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date (a consensus of the FASB Emerging Issues Task Force)”
	In February of 2013, the FASB issued ASC Update 2013-04, “Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date (a consensus of the FASB Emerging Issues Task Force.)”  ASC Update 2013-04 provides guidance on the measurement and disclosure of obligations resulting from joint and several liability arrangements for which the total obligation is fixed at the reporting date.  This update is effective for reporting periods beginning after December 15, 2013.  Chugach will begin application of ASC 2013-04 on January 1, 2014.  Adoption is not anticipated to have any incremental effect on results of operations, financial position, and cash flows.
	(3)    Recent Accounting Pronouncements (continued)
	ASC Update 2013-02 “Comprehensive Income (Topic 220): Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income”
	In January of 2013, the FASB issued ASC Update 2013-02, “Comprehensive Income (Topic 220): Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income.”  ASC Update 2013-02 expands the disclosure requirements for amounts reclassified out of accumulated other comprehensive income.  This update is effective for reporting periods beginning after December 15, 2012.  Chugach began application of ASC 2013-02 on January 1, 2013.  Chugach does not have any items included in other comprehensive income.  Therefore, assignable margins and comprehensive income are the same amount and the adoption did not have any effect on results of operations, financial position, and cash flows.
	ASC Update 2013-01 “Balance Sheet (Topic 210): Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities”
	In January of 2013, the FASB issued ASC Update 2013-01, “Balance Sheet (Topic 210): Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities.”  ASC Update 2013-01 clarifies the scope of Update 2011-11 to apply to derivatives accounted for in accordance with Topic 815, Derivatives and Hedging, including bifurcated embedded derivatives, repurchase agreements and reverse repurchase agreements, and securities borrowing and securities lending transactions that are either offset in accordance with Section 210-20-45 or Section 815-10-45 or subject to an enforceable master netting arrangement or similar agreement.  This update is effective for fiscal years beginning on or after January 1, 2013, and interim periods within those annual periods.  Chugach began application of ASC 2013-01 on January 1, 2013.  Adoption did not have any incremental effect on results of operations, financial position, and cash flows.
	ASC Update 2012-04 “Technical Amendments and Improvements”
	In October of 2012, the FASB issued ASC Update 2012-04, “Technical Amendments and Improvements.”  ASC Update 2012-04 amends a wide range of Topics in the FASB Codification, however the main provisions were to correct source literature guidance, provide clarity by updating and correcting wording and references, relocating guidance to a more appropriate location within the Codification, and conform terminology and clarify guidance to fully reflect the fair value measurement and disclosure requirements of Topic 820.  This update is effective for the first interim or annual reporting period beginning after December 15, 2012.  Chugach began application of ASC 2012-04 on January 1, 2013.  Adoption did not have any incremental effect on results of operations, financial position, and cash flows.

Fair_Values_Of_Assets_And_Liab

Fair Values Of Assets And Liabilities	12 Months Ended
	Dec. 31, 2013
Fair Values Of Assets And Liabilities [Abstract]	'
Fair Values Of Assets And Liabilities	'
	(4)    Fair Value of Assets and Liabilities
	Fair Value Hierarchy
	In accordance with FASB ASC 820, Chugach groups its financial assets and liabilities measured at fair value in three levels, based on the markets in which the assets and liabilities are traded and the reliability of the assumptions used to determine fair value.  These levels are:
	Level 1 – Valuation is based upon quoted prices for identical instruments traded in active exchange markets, such as the New York Stock Exchange.  Level 1 also includes United States Treasury and federal agency securities, which are traded by dealers or brokers in active markets.  Valuations are obtained from readily available pricing sources for market transactions involving identical assets or liabilities.
	Level 2 – Valuation is based upon quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-based
	valuation techniques for which all significant assumptions are observable in the market.
	Level 3 – Valuation is generated from model-based techniques that use significant assumptions not observable in the market.  These unobservable assumptions reflect Chugach’s estimates of assumptions that market participants would use in pricing the asset or liability.  Valuation techniques include use of option pricing models, discounted cash flow models and similar techniques.
	The table below presents the balance of Chugach’s marketable securities, money market and restricted cash equivalents assets measured at fair value on a recurring basis at December 31, 2013, and December 31, 2012.
			Total		Level 1		Level 2		Level 3
	31-Dec-13
	Marketable securities	$	10,308,533	$	10,308,533	$	0	$	0
	31-Dec-12
	Money market	$	2,829,397	$	2,829,397	$	0	$	0
	Marketable securities	$	10,158,016	$	10,158,016	$	0	$	0
	Chugach had no Level 3 assets or liabilities measured at fair value on a recurring basis.  Fair value estimates are dependent upon subjective assumptions and involve significant uncertainties resulting in variability in estimates with changes in assumptions.  The fair value of cash and cash equivalents, accounts receivable and payable, and other short-term monetary assets and liabilities approximate carrying value due to their short-term nature.

Regulatory_Matters

Regulatory Matters	12 Months Ended
	Dec. 31, 2013
Regulatory Matters [Abstract]	'
Regulatory Matters	'
	(5)    Regulatory Matters
	Fire Island Wind Project
	On October 10, 2011, the RCA issued an order approving Chugach’s request for assurance of cost recovery associated with a new power purchase agreement (PPA) between Chugach and Fire Island Wind, LLC (FIW), a special purpose entity wholly-owned by Cook Inlet Region, Inc.
	Associated with the approval of the PPA, Chugach submitted project status reports on March 31, 2012, June 29, 2012, October 31, 2012, and January 16, 2013. On January 30, 2014, Chugach submitted a status report regarding FIW integration and a cost reimbursement agreement related to possible impacts to an interconnected utility as a result of the project.  Chugach also requested that the RCA accept further updates beginning no later than July 31, 2014.
	2013 General Rate Case
	To reflect revenue and cost changes resulting from the expiration of HEA’s wholesale contract, Chugach submitted its 2013 Test Year General Rate Case to the RCA on November 19, 2013, to increase system base rate revenues by $16.0 million, or approximately 12.5 percent on total retail, MEA, and Seward base rate revenues of $127.4 million.  On January 2, 2014, the RCA approved the submitted rates on an interim and refundable basis. Retail rates were effective January 2, 2014, and wholesale rate changes were effective February 1, 2014, for purchases beginning January 1, 2014.    The increase, net of both base rate increases and fuel savings, to Chugach retail end-users is approximately 6 percent, while the net increase to retail end-users of MEA and Seward is approximately 8 percent and 5 percent, respectively.
	2012 General Rate Case
	To reflect cost changes resulting from commercial operation of SPP, Chugach submitted a general rate case to the RCA on December 21, 2012, to increase system base rate revenues by $30.0 million, or approximately 26 percent on total base rate revenues of $115.0 million.  The proposed rates became effective on an interim and refundable basis beginning in February of 2013.  In a separate filing Chugach adjusted fuel rates to reflect efficiency improvements associated with the commercial operation of SPP and made these reduced fuel rates effective at the same time as the requested general rate case increases.  This allowed the interim base rate increases to be synchronized with expected reductions in fuel cost recovery rates.
	The filing also requested approval of a major expansion of Chugach’s operating tariff to include both firm and non-firm transmission wheeling service and attendant ancillary services in support of third-party transactions on the Chugach system.  The main purpose of the expansion is to accommodate anticipated wheeling services after expiration of the HEA and MEA wholesale customer contracts.
	(5)    Regulatory Matters (continued)
	On February 1, 2013, Chugach submitted a supplemental filing to the RCA removing the impacts associated with a one-year amortization of distribution storm-related costs from its retail revenue requirement.  On February 6, 2013, the RCA opened Docket U-13-007 and issued Order No. 1 approving Chugach’s supplemental filing for rates effective February 6, 2013, on an interim and refundable basis.  In addition, the RCA also approved Chugach’s request to assess transmission wheeling charges on economy energy transactions that originate from the Chugach system.
	The increase, net of both base rate increases and fuel savings, to Chugach retail end-users is approximately 6 percent, while the net increase to retail end-users of Chugach’s wholesale customers is approximately 4 percent to 7 percent.  Consistent with its practice the RCA required Chugach, at its option, to either place the interim and refundable amounts received into an escrow account or pay an annualized interest rate of 10.5 percent on any future refunds required in the docket.  Chugach elected to place the interim and refundable amounts into escrow.
	Intervener testimony was filed with the RCA on August 23, 2013.  Both before and after those filings, Chugach has been engaged in discussions with the intervening parties to resolve the outstanding issues in the case.  The RCA accepted stipulations that resolved the majority of the issues in the case.  Chugach filed reply testimony on October 23, 2013, which proposed changes to its rate increase request, including a downward adjustment to its system revenue requirement by $0.2 million, which represents a 0.1 percent reduction to its system base rate revenue requirement of $143.0 million.
	On December 10, 2013, Chugach submitted a petition to the RCA to release all escrowed funds in excess of $0.5 million, which Chugach will keep in escrow to cover any refunding required at the conclusion of the case.  This $0.5 million is well in excess of the approximately $0.2 million needed to cover the refunds under the settlement.  The RCA approved Chugach’s petition on December 27, 2013.
	A hearing on the case took place in December of 2013 to resolve the remaining transmission issues in the case.
	On March 14, 2014, the RCA issued Order No. 16 affirming the acceptance of the stipulations entered among the parties in the case.  In the order, the RCA approved Chugach’s requested ratemaking treatment of select transmission facilities on its system.  In conjunction with the approval, Chugach is required to notify the RCA upon the completion of its transmission power flow study required by stipulation.  The RCA required Chugach to submit by April 14, 2014, a retail refund plan, updated rate calculations and attendant tariff revisions reflecting the results of the stipulations that were accepted by the RCA.
	(5)    Regulatory Matters (continued)
	Natural Gas Contract Submittals
	Gas Sale and Purchase Agreement between Chugach and Hilcorp Alaska, LLC
	On July 12, 2013, Chugach submitted a new gas purchase agreement with Hilcorp Alaska, LLC (Hilcorp) to the RCA.  The new agreement will supply gas from January 1, 2015, through March 31, 2018.  The total amount of gas under the contract is estimated to be 17.7 billion cubic feet (Bcf).  The new agreement is designed to fill the balance of Chugach’s unmet needs in 2015 and 2016, up to 100% of unmet needs in 2017 and up to 100% of its total needs in the first quarter of 2018.
	On September 10, 2013, the RCA issued an order approving the agreement and the recovery of the gas costs incurred under the agreement through Chugach's fuel and purchased power cost adjustment process.
	Gas Sale and Purchase Agreement between Chugach and Cook Inlet Energy, LLC
	On September 30, 2013, Chugach submitted a new gas purchase agreement with Cook Inlet Energy, LLC (CIE) to the RCA for natural gas deliveries commencing April 1, 2014, and terminating on March 31, 2018.  The agreement does not provide a current commitment to purchase any volume of gas but rather provides for the parties to meet and confer each year on the possible volumes of gas that could be sold and delivered in the next contract year or such other period as may be agreed.  This structure accommodates on-going gas development work by CIE and provides additional diversity in Chugach’s sources of natural gas to meet system load requirements.  On November 25, 2013, the RCA approved the agreement and the recovery of all gas costs incurred under the agreement through Chugach’s fuel and purchased power cost adjustment process.

Utility_Plant

Utility Plant	12 Months Ended
	Dec. 31, 2013
Utility Plant [Abstract]	'
Utility Plant	'
	(6)    Utility Plant
	Major classes of utility plant as of December 31 are as follows:
	Electric plant in service:	2013		2012
	Steam production plant	$	60,462,671	$	60,462,671
	Hydraulic production plant		20,546,809		20,513,746
	Other production plant		122,051,709		127,980,607
	Transmission plant		249,483,480		252,910,740
	Distribution plant		258,474,600		257,587,220
	General plant		48,517,709		51,901,426
	Unclassified electric plant in service1		369,280,657		109,023,464
	Intangible plant1		4,710,912		4,710,912
	Other1		1,828,409		6,690,723
	Total electric plant in service		1,135,356,956		891,781,509
	Construction work in progress2		28,674,163		263,459,794
	Total electric plant in service and construction work in progress	$	1,164,031,119	$	1,155,241,303
	1Unclassified electric plant in service consists of complete unclassified general plant, generation plant, transmission plant and distribution plant.  Depreciation of unclassified electric plant in service has been included in functional plant depreciation accounts in accordance with the anticipated eventual classification of the plant investment.  Intangible plant represents Chugach's share of a Bradley Lake transmission line financed internally.  Other represents Electric Plant Held for Future Use.
	2The amount associated with the construction of SPP included in construction work in progress was $245.5 million at December 31, 2012.

Investments_In_Associated_Orga

Investments In Associated Organizations	12 Months Ended
	Dec. 31, 2013
Investments In Associated Organizations [Abstract]	'
Investments In Associated Organizations	'
	(7)    Investments in Associated Organizations
	Investments in associated organizations include the following at December 31:
		2013		2012
	NRUCFC	$	6,095,980	$	6,095,980
	CoBank		4,044,338		4,392,948
	NRUCFC Capital Term Certificates and other		63,875		63,755
	Total investments in associated organizations	$	10,204,193	$	10,552,683
	The Farm Credit Administration, CoBank's federal regulators, requires minimum capital adequacy standards for all Farm Credit System institutions.  Loan agreements and financing arrangements with CoBank and NRUCFC require, as a condition of the extension of credit, that an equity ownership position be established by all borrowers.

Deferred_Charges_And_Credits

Deferred Charges And Credits	12 Months Ended
	Dec. 31, 2013
Deferred Charges And Credits [Abstract]	'
Deferred Charges And Credits	'
	(8)    Deferred Charges and Credits
	Deferred Charges
	Deferred charges, or regulatory assets, net of amortization, consisted of the following at December 31:
		2013		2012
	Debt issuance and reacquisition costs	$	3,611,498	$	4,126,529
	Refurbishment of transmission equipment		132,717		141,976
	Feasibility studies		912,537		76,390
	Beluga gas compression		1,526,599		2,035,466
	Cooper Lake relicensing / projects		5,670,314		5,800,417
	Fuel supply negotiations		971,209		815,451
	Major overhaul of steam generating unit		1,285,942		1,510,046
	Other regulatory deferred charges		1,759,448		4,473,037
	Bond interest - market risk management		6,960,044		7,527,357
	Environmental matters and other		1,160,223		1,205,574
	Total deferred charges	$	23,990,531	$	27,712,243
	Deferred charges, or regulatory assets, not currently being recovered in rates charged to consumers, consisted of the following at December 31:
		2013		2012
	Fuel supply (negotiations/studies/compression)	$	231,712	$	1,072,002
	Studies and other		336,017		236,401
	Wind project		34,543		391,285
	Financing related costs		0		1,757,624
	Beluga Unit 8 inspection		0		1,061,838
	Total deferred charges	$	602,272	$	4,519,150
	We believe all regulatory assets not currently being recovered in rates charged to consumers are probable of recovery in the future based upon prior recovery of similar costs allowed by our regulator.  The recovery of regulatory assets is approved by the RCA either in standard SRFs, general rate case filings or specified independent requests. In most cases, deferred charges are recovered over the life of the underlying asset.
	(8)    Deferred Charges and Credits (continued)
	Deferred Credits
	Deferred credits, or regulatory liabilities, at December 31 consisted of the following:
		2013		2012
	Refundable consumer advances for construction	$	773,089	$	777,323
	Estimated initial installation costs for meters		104,037		92,149
	Post retirement benefit obligation		899,700		899,700
	Total deferred costs	$	1,776,826	$	1,769,172

Patronage_Capital

Patronage Capital	12 Months Ended
	Dec. 31, 2013
Patronage Capital [Abstract]	'
Patronage Capital	'
	(9)    Patronage Capital
	Chugach has a Board-approved capital credit retirement policy, which is contained in Chugach’s Financial Forecast.  This establishes, in general, a plan to return the capital credits of wholesale and retail customers based on the members’ proportionate contribution to Chugach’s assignable margins.  At December 31, 2013, Chugach had $162,749,889 of patronage capital (net of capital credits retired in 2013), which included $152,205,846 of patronage capital that had been assigned and $10,544,043 of patronage capital to be assigned to its members.  Approval of actual capital credit retirements is at the discretion of Chugach's Board.  Chugach records a liability when the retirements are approved by the Board.  During 2008, the Board approved the deferral of capital credit retirements after 2009, excluding discounted capital credits, due to the construction of SPP and the anticipated loss of wholesale load in 2013 and 2014.  In December of 2013, the Board resumed its capital credit retirement program.  Capital credits retired, net of HEA’s allocations, were $1,626,828,  $48,079, and $309,188 for the years ended December 31, 2013, 2012, and 2011, respectively.
	The Second Amended and Restated Indenture of Trust (the Indenture) and the CoBank Amended and Restated Master Loan Agreement prohibit Chugach from making any distribution of patronage capital to Chugach’s customers if an event of default under the Indenture or debt agreements exists.  Otherwise, Chugach may make distributions to Chugach’s members in each year equal to the lesser of 5 percent of Chugach’s patronage capital or 50 percent of assignable margins for the prior fiscal year.  This restriction does not apply if, after the distribution, Chugach’s aggregate equities and margins as of the end of the immediately preceding fiscal quarter are equal to at least 30 percent of Chugach’s total liabilities and equities and margins.
	Chugach entered into an agreement with HEA to return all of its patronage capital within five years after expiration of its power sales agreement, which is December 31, 2013.  This patronage capital retirement was related to a settlement agreement associated with the 2005 Test Year General Rate Case (Docket U-06-134).  The RCA accepted the parties’ settlement agreement on August 9, 2007.  HEA’s patronage capital payable was $7.9 million and $6.9 million at December 31, 2013 and 2012, respectively.
	(9)    Patronage Capital (continued)
	Capital credits retired, net of HEA’s allocations, were $1,626,828, $48,079, and $309,188 for the years ended December 31, 2013, 2012, and 2011, respectively.  With the exception of HEA’s patronage capital payable, the outstanding liability for capital credits authorized but not paid at December 31, 2013 was $1,470,263.  With the exception of HEA’s patronage capital payable, there was no outstanding liability for capital credits authorized but not paid at December 31, 2012.

Other_Equities

Other Equities	12 Months Ended
	Dec. 31, 2013
Other Equities [Abstract]	'
Other Equities	'
	(10)  Other Equities
	A summary of other equities at December 31 follows:
		2013		2012
	Nonoperating margins, prior to 1967	$	23,625	$	23,625
	Donated capital		1,742,889		1,647,869
	Unclaimed capital credit retirement1		9,679,404		9,700,861
	Total other equities	$	11,445,918	$	11,372,355
	1Represents unclaimed capital credits that have met all requirements of section 34.45.200 of Alaska’s    unclaimed property law and has therefore reverted to Chugach.

Debt

Debt	1 Months Ended
	Dec. 31, 2012
Debt [Abstract]	'
Debt	'
	(11)  Debt
	Long-term obligations at December 31 are as follows:	2013			2012
	CoBank 3 and 4, 2.52% variable rate notes maturing in 2022, with interest payable monthly and principal due annually beginning in 2003	$	29,680,420		$	31,756,775
	2011 Series A Bond of 4.20%, maturing in 2031, with interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012		81,000,000			85,500,000
	2011 Series A Bond of 4.75%, maturing in 2041, with interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012		172,666,666			178,833,333
	2012 Series A Bond of 4.01%, maturing in 2032, with interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2013		71,250,000			75,000,000
	2012 Series A Bond of 4.41%, maturing in 2042, with interest payable semi-annually March 15 and September 15 and principal due annually between 2013 and 2020 and between 2032 and 2042		117,000,000			125,000,000
	2012 Series A Bond of 4.78%, maturing in 2042, with interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2023		50,000,000			50,000,000
	Total long-term obligations	$	521,597,086		$	546,090,108
	Less current installments		24,682,812			24,493,022
	Long-term obligations, excluding current installments	$	496,914,274		$	521,597,086
	Covenants
	Effective January 20, 2011, Chugach is required to comply with all covenants set forth in the Indenture that secured the 2002 Series A Bonds through February 1, 2012, and now secures the 2011 Series A Bonds, the 2012 Series A Bonds and the 2011 promissory note to CoBank, which has replaced the outstanding CoBank 3, 4 and 5 promissory notes.
	(11)  Debt (continued)
	On January 19, 2011, CoBank and Chugach replaced the CoBank 3, 4 and 5 promissory notes with a promissory note that is governed by the Amended and Restated Master Loan Agreement, which is now secured by the Indenture dated January 20, 2011.
	Chugach is also required to comply with the 2010 Credit Agreement, between Chugach and NRUCFC, KeyBank National Association, Bank of America, N.A., Bank of Montreal, CoBank, ACB and Chang Hwa Commercial Bank, Ltd., Los Angeles Branch dated June 29, 2012, governing loans and extensions of credit associated with Chugach’s commercial paper program, in an aggregate principal amount not exceeding $100.0 million at any one time outstanding.
	Chugach is also required to comply with other covenants set forth in the Revolving Line of Credit Agreement with NRUCFC.
	Security
	The Indenture, which became effective on January 20, 2011, imposes a lien on substantially all of Chugach’s assets to secure Chugach’s long-term debt obligations.  Assets that are generally not subject to the lien of the Indenture include cash (other than cash deposited with the indenture trustee); instruments and securities; patents, trademarks, licenses and other intellectual property; vehicles and other movable equipment; inventory and consumable materials and supplies; office furniture, equipment and supplies; computer equipment and software; office leases; other leasehold interests for an original term of less than five years; contracts (other than power sales agreements with members having an original term exceeding three years, certain contracts specifically identified in the indenture, and other contracts relating to the ownership, operation or maintenance of generation, transmission or distribution facilities); non-assignable permits, licenses and other contract rights; timber and minerals separated from land; electricity, gas, steam, water and other products generated, produced or purchased; other property in which a security interest cannot legally be perfected by the filing of a Uniform Commercial Code financing statement, and certain parcels of real property specifically excepted from the lien of the Indenture.  The lien of the Indenture may be subject to various permitted encumbrances that include matters existing on the date of the Indenture or the date on which property is later acquired; reservations in United States patents; non-delinquent or contested taxes, assessments and contractors’ liens; and various leases, rights-of-way, easements, covenants, conditions, restrictions, reservations, licenses and permits that do not materially impair Chugach’s use of the mortgaged property in the conduct of Chugach’s business.
	Rates
	The Indenture also requires Chugach, subject to any necessary regulatory approval, to establish and collect rates reasonably expected to yield margins for interest equal to at least 1.10 times total interest expense.  If there occurs any material change in the circumstances contemplated at the time rates were most recently reviewed, the Indenture requires Chugach to seek appropriate adjustment to those rates so that they would generate revenues reasonably expected to yield margins for interest equal to at least 1.10 times interest charges, provided, however, upon review
	(11)  Debt (continued)
	of rates based on a material change in circumstances, rates are required to be revised in order to comply and there are less than six calendar months remaining in the current fiscal year, Chugach can revise its rates so as to reasonably expect to meet the covenant for the next succeeding 12-month period after the date of any such revision.
	The CoBank Master Loan Agreement also required Chugach to establish and collect rates reasonably expected to yield margins for interest equal to at least 1.10 times interest expense.  The Amended and Restated Master Loan Agreement with CoBank, which became effective on January 19, 2011, did not change this requirement.
	The 2010 Credit Agreement governing the unsecured facility providing liquidity for Chugach’s Commercial Paper Program requires Chugach to maintain minimum margins for interest of at least 1.10 times interest charges for each fiscal year.  Margins for interest generally consist of Chugach’s assignable margins plus total interest expense.
	Distributions to Members
	Under the Indenture and debt agreements, Chugach is prohibited from making any distribution of patronage capital to Chugach’s customers if an event of default under the Indenture or debt agreements exists.  Otherwise, Chugach may make distributions to Chugach’s members in each year equal to the lesser of 5 percent of Chugach’s patronage capital or 50 percent of assignable margins for the prior fiscal year.  This restriction does not apply if, after the distribution, Chugach’s aggregate equities and margins as of the end of the immediately preceding fiscal quarter are equal to at least 30 percent of Chugach’s total liabilities and equities and margins.
	Maturities of Long‑term Obligations
	Long-term obligations at December 31, 2013, mature as follows:
	Year ending			2011 Series A			CoBank Note		2012 Series A			Total
	31-Dec			Bonds					Bonds
	2014			10,666,667			2,266,145		11,750,000			24,682,812
	2015			10,666,667			2,473,110		10,750,000			23,889,777
	2016			10,666,667			2,699,313		10,750,000			24,115,980
	2017			10,666,667			2,945,954		10,750,000			24,362,621
	2018			10,666,667			3,215,267		10,750,000			24,631,934
	Thereafter			200,333,331			16,080,631		183,500,000			399,913,962
			$	253,666,666		$	29,680,420	$	238,250,000		$	521,597,086
	(11)  Debt (continued)
	Lines of credit
	Chugach maintains a $50.0 million line of credit with NRUCFC.  Chugach did not utilize this line of credit in 2013, and therefore had no outstanding balance at December 31, 2013.  In addition, Chugach did not utilize this line of credit during 2012 and had no outstanding balance at December 31, 2012.  The borrowing rate is calculated using the total rate per annum and may be fixed by NRUCFC. The borrowing rate was 2.90 percent at December 31, 2013, and December 31, 2012.
	The NRUCFC Revolving Line Of Credit Agreement requires that Chugach, for each 12-month period, for a period of at least five consecutive days, pay down the entire outstanding principal balance.
	On September 26, 2012, the Board approved a resolution to renew this line of credit under substantially the same terms as the previous agreement.  The NRUCFC line of credit now expires October 12, 2017.
	This line of credit is immediately available for unconditional borrowing.
	Commercial Paper
	On November 17, 2010, Chugach entered into a $300.0 million Unsecured Credit Agreement, which is used to back Chugach’s Commercial Paper Program.  The participating banks were NRUCFC, Bank of America, N.A., KeyBank National Association, JPMorgan Chase Bank, N.A., Bank of Montreal, CoBank, ACB, Goldman Sachs Bank USA, Bank of Taiwan, Los Angeles Branch and Chang Hwa Commercial Bank, Ltd., Los Angeles Branch.  Effective May 4, 2012, Chugach reduced the commitment amount to $100.0 million and on June 29, 2012, amended and extended the Credit Agreement to update the pricing and extend the term.  The new pricing includes an all-in drawn spread of one month London Interbank Offered Rate (LIBOR) plus 107.5 basis points, along with a 17.5 basis points facility fee (based on an A- unsecured debt rating).  The Amended Unsecured Credit Agreement now expires on November 17, 2016.  The participating banks include NRUCFC, KeyBank National Association, Bank of America, N.A., Bank of Montreal, CoBank and Chang Hwa Commercial Bank, Ltd., Los Angeles Branch.  Our commercial paper can be repriced between one day and 270 days.  Chugach is expected to continue to issue commercial paper in 2014, as needed, however, the requirement for short-term borrowing has decreased.
	Chugach had $30.0 million and $11.5 million of commercial paper outstanding at December 31, 2013 and 2012, respectively.
	(11)  Debt (continued)
	The following table provides information regarding 2013 monthly average commercial paper balances outstanding (dollars in millions), as well as corresponding weighted average interest rates:
	Month		Average		Weighted Average		Month	Average		Weighted Average
			Balance		Interest Rate			Balance		Interest Rate
	January		$5.90		0.27		July	$33.40		0.23
	February		$0.10		0.25		August	$35.00		0.21
	March		$23.20		0.29		September	$42.10		0.21
	April		$40.00		0.26		October	$49.90		0.23
	May		$39.70		0.24		November	$52.70		0.19
	June		$34.30		0.24		December	$53.10		0.2
	Financing
	On January 11, 2012, Chugach issued $75.0 million of First Mortgage Bonds, 2012 Series A, due March 15, 2032 (Tranche A), $125.0 million of First Mortgage Bonds, 2012 Series A, due March 15, 2042 (Tranche B) and $50.0 million of First Mortgage Bonds, 2012 Series A, due March 15, 2042 (Tranche C), for the purpose of repaying outstanding commercial paper used to finance SPP construction and for general corporate purposes.  The 2012 Series A Bonds (Tranche A) will mature on March 15, 2032, and will bear interest at 4.01 percent per annum.  The 2012 Series A Bonds (Tranche B) will mature on March 15, 2042, and will bear interest at 4.41 percent per annum.  The 2012 Series A Bonds (Tranche C) will mature on March 15, 2042, and will bear interest at 4.78 percent per annum.  Interest will be paid semi-annually March 15 and September 15, commencing on September 15, 2012.  The 2012 Series A Bonds (Tranche A) will pay principal in equal installments on an annual basis beginning March 15, 2013, resulting in an average life of approximately 10.7 years.  The 2012 Series A Bonds (Tranche B) will pay principal between March 15, 2013 and March 15, 2020 and between March 15, 2032 and March 15, 2042, resulting in an average life of approximately 15.7 years.  The 2012 Series A Bonds (Tranche C) will pay principal in equal installments on an annual basis beginning March 15, 2023, resulting in an average life of approximately 20.7 years.  The bonds and all other long-term debt obligations are secured by a lien on substantially all of Chugach’s assets, pursuant to the Indenture, which became effective on January 20, 2011.
	On January 21, 2011, Chugach issued $90.0 million of First Mortgage Bonds, 2011 Series A, due March 15, 2031 and $185.0 million of First Mortgage Bonds, 2011 Series A, due March 15, 2041 for the purpose of refinancing the 2001 and 2002 Series A Bonds due March 15, 2011, and February 1, 2012, respectively, and for general corporate purposes.  As anticipated, on February 1, 2012, Chugach retired its 2002 Series A Bonds with proceeds from the 2011 Series A bond issuance.  The 2011 Series A Bonds due March 15, 2031, will bear interest at 4.20 percent per annum, payable semi-annually on March 15 and September 15 commencing on September 15, 2011.  Principal on the 2011 Series A Bonds due March 15, 2031 will be paid in equal annual installments beginning March 15, 2012, resulting in an average life of approximately 10 years.  The 2011 Series A Bonds
	(11)  Debt (continued)
	due March 15, 2041, will bear interest at 4.75 percent per annum, payable semi-annually on March 15 and September 15, commencing on September 15, 2011.  Principal on the 2011 Series A Bonds due March 15, 2041, will be paid in equal annual installments beginning March 15, 2012, resulting in an average life of approximately 15.5 years.
	Chugach has a term loan facility with CoBank.  Loans made under this facility are evidenced by the 2011 CoBank Note, which is governed by the Amended and Restated Master Loan Agreement dated January 19, 2011, and secured by the Indenture.
Fair Value of Debt Instruments
The fair value of long-term debt has been determined using discounted future cash flows at borrowing rates currently available to Chugach. Level 1 measurement was used to determine the fair value of the 2011 and 2012 Series A Bonds. Level 2 measurements were used to determine all other long-term obligations.  The estimated fair value (in thousands) of the long-term obligations included in the financial statements at December 31 is as follows:
	Carrying Value			Fair Value
Long-term obligations (including current installments)	$	521,597		$	512,435

Employee_Benefit_Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2013
Employee Benefit Plans [Abstract]	'
Employee Benefit Plans	'
	(12)  Employee Benefit Plans
	Pension Plans
	Pension benefits for substantially all union employees are provided through the Alaska Electrical Pension Trust Fund and the UNITE HERE National Retirement Fund, multi-employer plans.  Chugach pays an hourly amount per eligible union employee pursuant to the collective bargaining unit agreements.  In these master, multi-employer plans, the accumulated benefits and plan assets are not determined or allocated separately to the individual employer.
	Pension benefits for non-union employees are provided by the National Rural Electric Cooperative Association (NRECA) Retirement and Security Plan (RS Plan).  The RS Plan is a defined benefit pension plan qualified under Section 401 and tax-exempt under Section 501(a) of the Internal Revenue Code.  Under ASC 960, “Topic 960 – Plan Accounting – Defined Benefit Pension Plans,” the RS Plan is a multi-employer plan, in which the accumulated benefits and plan assets are not determined or allocated separately to individual employers.  Chugach makes annual contributions to the RS Plan equal to the amounts accrued for pension expense.
	Chugach made contributions to all significant pension plans for the years ended December 31, 2013, 2012 and 2011 of $6.8 million, $6.6 million and $6.0 million, respectively.  The rate and number of employees in all significant pension plans did not materially change for the years ended December 31, 2013, 2012 and 2011.
	(12)  Employee Benefit Plans (continued)
	Pension Plans (continued)
	The following table provides information regarding pension plans which Chugach considers individually significant:
		Alaska Electrical Pension Plan3			NRECA Retirement Security Plan3
	Employer Identification Number	92-6005171			53-0116145
	Plan Number	1			333
	Year-end Date	31-Dec			31-Dec
	Expiration Date of CBA's	30-Jun-17			N/A2
	Subject to Funding Improvement Plan	No			No4
	Surcharge Paid	N/A			N/A4
		2013	2012	2011	2013	2012	2011
	Zone Status	Green	Green	Green	N/A1	N/A1	N/A1
	Required minimum contributions	None	None	None	N/A	N/A	N/A
	Contributions (in millions)	$3.40	$3.60	$3.00	$3.40	$3.00	$3.00
	Contributions > 5% of total plan contributions	Yes	Yes	Yes	No	No	No
	1A “zone status” determination is not required, and therefore not determined under the Pension Protection Act (PPA) of 2006.
	2The CEO is the only non-union employee subject to an employment agreement, which is effective through July 17, 2016.
	3The Alaska Electrical Pension Plan is publicly available.  The NRECA Retirement Security Plan is available on Chugach’s website at www.chugachelectric.com.
	4The provisions of the PPA do not apply to the RS Plan, therefore, funding improvement plans and surcharges are not applicable.  Future contribution requirements are determined each year as part of the actuarial valuation of the RS Plan and may change as a result of plan experience.
	Health and Welfare Plans
	Health and welfare benefits for union employees are provided through the Alaska Electrical Health and Welfare Trust and the Alaska Hotel, Restaurant and Camp Employees Health and Welfare and Pension Trust Fund.  Chugach participates in multi-employer plans that provide substantially all union workers with health care and other welfare benefits during their employment with Chugach.  Chugach pays a defined amount per union employee pursuant to
	collective bargaining unit agreements.  Amounts charged to benefit costs and contributed to the health and welfare plans for these benefits for the years ending December 31, 2013, 2012, and 2011 were $4.1 million, $4.3 million, and $3.7 million, respectively.
	Chugach participates in a multi-employer plan through the Group Benefits Program of NRECA for non-union employees.  Amounts charged to benefit cost and contributed to this plan for those benefits for the years ended December 31, 2013, 2012, and 2011 totaled $2.9 million, $2.5 million, and $2.4 million respectively.
	(12)  Employee Benefit Plans (continued)
	Money Purchase Pension Plan
	Chugach participates in a multi-employer defined contribution money purchase pension plan covering some employees who are covered by a collective bargaining agreement.  Contributions to the Plan are made based on a percentage of each employee’s compensation.  Contributions to the money purchase pension plan for the years ending December 31, 2013, 2012 and 2011 were $147.9 thousand, $141.0 thousand and $128.7 thousand, respectively.
	401(k) Plan
	Chugach has a defined contribution 401(k) retirement plan which covers substantially all employees who, effective January 1, 2008, can participate immediately.  Employees who elect to participate may contribute up to the Internal Revenue Service’s maximum of $17,500,  $17,000 and $16,500 in 2013, 2012 and 2011 respectively, and allowed catch-up contributions for those over 50 years of age of $5,500 in 2013, 2012 and 2011.  Chugach does not make contributions to the plan.
	Deferred Compensation
	Effective January 1, 2011, Chugach participates in Vanguard’s unfunded Deferred Compensation Program (the Program) to allow highly compensated employees who elect to participate in the Program to defer a portion of their current compensation and avoid paying tax on the deferrals until received.  The program is a non-qualified plan under Internal Revenue Code 457(b).
	Deferred compensation accounts are established for the individual employees, however, they are considered to be owned by Chugach until a distribution is made.  The amounts credited to the deferred compensation account, including gains or losses, are retained by Chugach until the entire amount credited to the account has been distributed to the participant or to the participant’s beneficiary.  The balance of the Program for the years ending December 31, 2013, 2012 and 2011 was $536,546, $570,027 and $420,783, respectively.
	Potential Termination Payments
	Pursuant to a Chugach Operating Policy, non-represented employees, including the executive officers except the Chief Executive Officer, who are terminated by Chugach for reasons unrelated to employee performance are entitled to severance pay for each year or partial year of service as follows:  two weeks for each year of service to a maximum of 26 weeks for 13 years or more of service.

Bradley_Lake_Hydroelectric_Pro

Bradley Lake Hydroelectric Project	12 Months Ended
	Dec. 31, 2013
Bradley Lake Hydroelectric Project [Abstract]	'
Bradley Lake Hydroelectric Project	'
	(13)  Bradley Lake Hydroelectric Project
	Chugach is a participant in the Bradley Lake Hydroelectric Project (Bradley Lake).  Bradley Lake was built and financed by the Alaska Energy Authority (AEA) through State of Alaska grants and $166.0 million of revenue bonds.  Chugach and other participating utilities have entered into take‑or‑pay power sales agreements under which shares of the project capacity have been purchased and the participants have agreed to pay a like percentage of annual costs of the project (including ownership, operation and maintenance costs, debt service costs and amounts required to maintain established reserves).  Under these take‑or‑pay power sales agreements, the participants have agreed to pay all project costs from the date of commercial operation even if no energy is produced.  Chugach has a 30.4 percent share, or 27.4 megawatts (MW) as currently operated, of the project’s capacity.  The share of Bradley Lake indebtedness for which we are responsible is approximately $26.6 million.  Upon the default of a Bradley Lake participant, and subject to certain other conditions, AEA is entitled to increase each participant’s share of costs pro rata, to the extent necessary to compensate for the failure of another participant to pay its share, provided that no participant’s percentage share is increased by more than 25 percent.  Upon default, Chugach could be faced with annual expenditures of approximately $5.2 million as a result of Chugach’s Bradley Lake take-or-pay obligations.  Management believes that such expenditures, if any, would be recoverable through the fuel recovery process.
	The State of Alaska provided an initial grant for work on a project to divert water from Battle Creek into Bradley Lake.  The project is being managed by the Alaska Energy Authority.  Based on stream flow measurements from 1991 through 1993, diverting a portion of Battle Creek into Bradley Lake has the potential to increase annual energy output up to 40,000 megawatt-hours (MWh).  Chugach would be entitled to 30.4 percent of the additional energy produced.
	The following represents information with respect to Bradley Lake at June 30, 2013 (the most recent date for which information is available).  Chugach's share of expenses was $4,882,163 in 2013, $4,223,784 in 2012, and $4,643,641 in 2011 and is included in purchased power in the accompanying financial statements.
	(In thousands)	Total	Proportionate Share
	Plant in service	$177,968	$54,102
	Long-term debt	80,117	24,356
	Interest expense	4,618	1,404
	Chugach's share of a Bradley Lake transmission line financed internally is included in Intangible Electric Plant.

Eklutna_Hydroelectric_Project

Eklutna Hydroelectric Project	12 Months Ended
	Dec. 31, 2013
Eklutna Hydroelectric Project [Abstract]	'
Eklutna Hydroelectric Project	'
	(14)  Eklutna Hydroelectric Project
	Along with two other utilities, Chugach purchased the Eklutna Hydroelectric Project from the federal government in 1997. Ownership was transferred from the United States Department of Energy’s Alaska Power Administration jointly to Chugach (30 percent), MEA (17 percent) and ML&P (53 percent).
	(14)  Eklutna Hydroelectric Project (continued)
	Plant in service in 2013 includes $4,562,310, net of accumulated depreciation of $1,854,083, which represents Chugach’s share of the Eklutna Hydroelectric Project.  In 2012, plant in service included $4,725,470, net of accumulated depreciation of $1,671,335.  The facility is operated by Chugach and maintained jointly by Chugach and ML&P.  Each participant contributes their proportionate share for operation, maintenance and capital improvement costs to the plant, as well as to the transmission line between Anchorage and the plant.  Under net billing arrangements, Chugach then reimburses MEA for their share of the costs.  Chugach’s share of expenses was $730,122, $682,757, and $662,035 in 2013, 2012, and 2011, respectively, and is included in purchased power, power production and depreciation expense in the accompanying financial statements.  ML&P performs major maintenance at the plant. Chugach performs the daily operation and maintenance of the power plant, providing personnel who perform daily plant inspections, meter reading, monthly report preparation, and other activities as required.

Commitments_And_Contingencies

Commitments And Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments And Contingencies [Abstract]	'
Commitments And Contingencies	'
	(15)  Commitments and Contingencies
	Contingencies
	Chugach is a participant in various legal actions, rate disputes, personnel matters and claims both for and against Chugach’s interests.  Management believes the outcome of any such matters will not materially impact Chugach’s financial condition, results of operations or liquidity.
	Concentrations
	Approximately 70 percent of our employees are members of the International Brotherhood of Electrical Workers (IBEW).  Chugach has three Collective Bargaining Unit Agreements (CBA) with the IBEW.  We also have an agreement with the Hotel Employees and Restaurant Employees (HERE).  All three IBEW CBA’s have been renewed through June 30, 2017.  The HERE contract has been renewed through June 30, 2016.
	Chugach is the principal supplier of power under a wholesale power contract with MEA and was the principal supplier of power under a wholesale power contract with HEA until December 31, 2013.  These contracts, including the fuel component, represented $103.1 million or 34 percent of sales revenue in 2013, $100.6 million or 39 percent in 2012, and $104.0 million or 37 percent in 2011.  The HEA contract expired December 31, 2013, and the MEA contract expires December 31, 2014.  Pursuant to contract provisions, notifications were made by MEA and HEA that neither organization intended to renew their contracts.  MEA advised Chugach that it desired to open discussions regarding power sales possibilities beyond 2014.  Chugach proposed a power supply offer to MEA on January 11, 2011, and again on January 31, 2012.  Chugach received a response on February 29, 2012, indicating that MEA was following the path its membership most favored and is moving forward with plans to build its own generation plant.  All rates are established by the RCA.
	(15)  Commitments and Contingencies (continued)
	Fuel Supply Contracts
	Chugach has fuel supply contracts from various producers at market terms.  Previous contracts expired at the end of the currently committed volumes in 2010 and 2011.  A gas supply contract between Chugach and ConocoPhillips Alaska, Inc. and ConocoPhillips, Inc. (collectively “ConocoPhillips”), was approved by the RCA effective August 21, 2009.  The new contract provided gas beginning in 2010 and will terminate December 31, 2016.  The total amount of gas under the contract is now estimated to be 60  Bcf.  The RCA approved a new natural gas supply contract with Marathon Alaska Production, LLC (MAP) effective May 17, 2010. This contract includes two contract extensions that were exercised in 2011.  Effective February 1, 2013, this gas purchase agreement was assigned to Hilcorp, who purchased MAP’s assets in Cook Inlet.  This contract provided gas beginning April 1, 2011, and will expire March 31, 2018.  The total amount of gas under contract is now estimated up to 40  Bcf.  These contracts fill 100 percent of Chugach’s needs through March 31, 2018.  All of the production is expected to come from Cook Inlet, Alaska.  In 2013, 87 percent of our power was generated from gas, with 47 percent generated at the Beluga Power Plant and 31 percent generated at SPP. In 2012 and 2011, 89 percent and 92 percent, respectively, of our power was generated from gas, with 83 percent and 79 percent generated at Beluga.
	The terms of the ConocoPhillips and Hilcorp agreements require Chugach to handle the natural gas transportation over the connecting pipeline systems.  Effective October 1, 2012, Chugach and Hilcorp entered into a gas exchange agreement to exchange gas between the east and west side of Cook Inlet.  This agreement terminated on September 30, 2013.  We have gas transportation agreements with ENSTAR Natural Gas Company (ENSTAR) and Hilcorp.  The following represents the cost of fuel purchased and or transported from various vendors as a percentage of total fuel costs for the years ended December 31:
		2013	2012	2011
	Marathon Oil Company	4.50%	72.00%	44.90%
	Chevron / Unocal / Hilcorp	46.40%	1.30%	16.10%
	ML&P	0.00%	0.00%	3.60%
	ConocoPhillips (COP)	42.80%	24.20%	31.90%
	ENSTAR	2.10%	2.20%	1.30%
	Hilcorp Pipeline	3.80%	0.00%	0.00%
	Miscellaneous	0.40%	0.30%	2.20%
	Patronage Capital Payable
	In 2007, Chugach entered into an agreement with HEA to return all of its patronage capital within five years after expiration of its power sales agreement, which was related to a settlement agreement associated with the 2005 Test Year General Rate Case (Docket U-06-134).  The agreement was contingent on the RCA accepting the parties’ settlement agreement in Docket U-06-134, which occurred on August 9, 2007.  HEA’s patronage capital should have been
	(15)  Commitments and Contingencies (continued)
	classified as a liability at that time.  HEA’s patronage capital was $6.5 million at December 31, 2010.  As the amount of the patronage capital was not material for any period, Chugach recorded an adjustment in the first quarter of 2011 to reclassify the amount of $6.5 million from patronage capital to patronage capital payable and is included in the retirement of capital credits on our Statements of Changes in Equities and Margins.  HEA’s patronage capital was $7.9 million at December 31, 2013 and $6.9 million at December 31, 2012, and is classified as patronage capital payable on our Balance Sheet.
	Regulatory Cost Charge
	In 1992, the State of Alaska Legislature passed legislation authorizing the Department of Revenue to collect a Regulatory Cost Charge from utilities to fund the governing regulatory commission, which is currently the RCA.  The tax is assessed on all retail consumers and is based on kilowatt-hour (kWh) consumption.  The tax is collected monthly and remitted to the State of Alaska quarterly.  The Regulatory Cost Charge has changed since its inception (November of 1992) from an initial rate of $0.000626 per kWh to the current rate of $0.000578,  effective July 1, 2013. The tax is reported on a net basis and the tax is not included in revenue or expense.
	Sales Tax
	Chugach collects sales tax on retail electricity sold to Kenai and Whittier consumers.  The tax is collected monthly and remitted to the Kenai Peninsula Borough quarterly.  Sales tax is reported
	on a net basis and the tax is not included in revenue or expense.
	Gross Receipts Tax
	Chugach pays to the State of Alaska a gross receipts tax in lieu of state and local ad valorem, income and excise taxes on electricity sold in the retail market.  The tax is accrued monthly and remitted annually.  The tax is reported on a net basis and the tax is not included in revenue.
	Production Taxes
	Production taxes on Chugach fuel purchases are paid directly to our gas producers and are recorded under “Fuel” in Chugach’s financial statements.
	Underground Compliance Charge
	In 2005, the Anchorage Municipal Assembly adopted an ordinance to require utilities to convert overhead distribution lines to underground.  To comply with the ordinance, Chugach must expend two percent of a  three-year average of gross retail revenue within the Municipality of Anchorage annually in moving existing distribution overhead lines underground.  Consistent with Alaska Statutes regarding undergrounding programs, Chugach is permitted to amend its rates by adding a two percent charge to its retail members’ bills to recover the actual costs of the
	(15)  Commitments and Contingencies (continued)
	program.  The rate amendments are not subject to RCA review or approval.  Chugach’s liability was $2,898,558 and $3,786,031 for this charge at December 31, 2013 and 2012, respectively.  These funds are used to offset the costs of the undergrounding program.
	Environmental Matters
	The Clean Air Act and Environmental Protection Agency (EPA) regulations under the Clean Air Act establish ambient air quality standards and limit the emission of many air pollutants.  New Clean Air Act regulations impacting electric utilities may result from future events or new regulatory programs.  Chugach is subject to these regulations, which have not had and are not expected to have a material effect on our results of operations, financial position, and cash flows.  While we cannot predict whether any additional new regulation would occur or its limitation, it is possible that new laws or regulations could increase our capital and operating costs.  Chugach has obtained Clean Air Act permits currently required for the operation of our generating facilities.
	Chugach is subject to numerous other environmental statutes including the Clean Water Act, the Resource Conservation and Recovery Act, the Toxic Substances Control Act, the Endangered Species Act, and the Comprehensive Environmental Response, Compensation and Liability Act and to the regulations implementing these statutes.  We do not believe that compliance with these statutes and regulations to date has had a material impact on our financial condition, results of operation or cash flows.  However, new laws or regulations, implementation of final regulations or changes in or new interpretations of these laws or regulations could result in significant additional capital or operating expenses.  Chugach follows proposed new regulations and existing regulation changes through industry associations and professional organizations.
	Economy Energy Sales
	On October 5, 2012, Chugach and GVEA finalized arrangements for Chugach to provide economy energy to GVEA until March of 2015.    Sales will be made under the terms and conditions of Chugach’s economy energy sales tariff.  The price to GVEA will include the cost of fuel, variable operations and maintenance expense, wheeling charges and a margin.  Chugach has also entered into specific gas supply arrangements to make economy energy sales to GVEA.
	Cooper Lake Hydroelectric Project
	The Cooper Lake Hydroelectric Project received a 50-year license from FERC in August of 2007.  A condition of that license is a requirement to construct a Stetson Creek diversion structure, a pipeline to Cooper Lake, and a bypass structure to release warmer water from Cooper Lake into Cooper Creek.  If the project is not feasible or if the cost estimate materially exceeds the terms of the license, Chugach has the option to request a license amendment.  At the time the project was being relicensed the estimated cost to complete the project was $12.0 million.  The current estimate to complete the project is now $21.9 million.  As an alternative to requesting a license amendment from FERC, Chugach requested grants from the State of Alaska.  Funding for
	(15)  Commitments and Contingencies (continued)
	this project includes $6.4 million in grants received with an additional $1.76 million pending authorization.  The Chugach Board authorized expenditures for the project November 15, 2012.  The diversion project began construction in 2013 and will be completed in 2014.  It will operate through the duration of the license.

Gain_On_Sale_Of_Asset

Gain On Sale Of Asset	12 Months Ended
	Dec. 31, 2013
Gain On Sale of Asset [Abstract]	'
Gain On Sale Of Asset	'
	(16)  Gain on  Sale of  Asset
	On July 12, 2011, Chugach sold the Bernice Lake Power Plant to AEEC and HEA.  Chugach recognized the proceeds from this sale as a liability on its Balance Sheet and continued to dispatch the power plant until the expiration of its power sales agreement with HEA.  In December of 2013, Chugach recognized the gain associated with this sale which amounted to $6.4 million.

Quarterly_Results_Of_Operation

Quarterly Results Of Operations (Unaudited)	12 Months Ended
	Dec. 31, 2013
Quarterly Results Of Operations (Unaudited) [Abstract]	'
Quarterly Results Of Operations (Unaudited)	'
	(17)  Quarterly Results of Operations (unaudited)
	2013 Quarter Ended
		Dec. 31		Sept. 30		30-Jun		31-Mar
	Operating Revenue	$	81,068,132	$	71,715,353	$	74,776,425	$	77,748,517
	Operating Expense		73,756,307		67,061,684		70,076,488		67,844,018
	Net Interest		6,014,808		6,016,792		6,058,246		5,291,626
	Net Operating Margins		1,297,017		-1,363,123		-1,358,309		4,612,873
	Nonoperating Margins		6,918,314		226,803		-18,235		228,703
	Assignable Margins	$	8,215,331	$	-1,136,320	$	-1,376,544	$	4,841,576
	2012 Quarter Ended
		Dec. 31		Sept. 30		30-Jun		31-Mar
	Operating Revenue	$	74,483,455	$	62,675,511	$	58,631,729	$	71,180,773
	Operating Expense		68,250,215		60,200,529		55,725,151		64,019,060
	Net Interest		3,492,044		3,495,865		3,542,676		3,872,346
	Net Operating Margins		2,741,196		-1,020,883		-636,098		3,289,367
	Nonoperating Margins		632,775		261,487		123,962		133,701
	Assignable Margins	$	3,373,971	$	-759,396	$	-512,136	$	3,423,068

Significant_Accounting_Policie1

Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2013
Significant Accounting Policies [Abstract]	'
Management Estimates	'
	a. Management Estimates
	In preparing the financial statements in conformity with United States generally accepted accounting principles (GAAP), the management of Chugach is required to make estimates and assumptions relating to the reporting of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the balance sheet and revenues and expenses for the reporting period.  Estimates include allowance for doubtful accounts, workers compensation, deferred charges and credits, unbilled revenue, the estimated useful life of utility plant and the cost of removal obligation.  Actual results could differ from those estimates.
Regulation	'
	b. Regulation
	The accounting records of Chugach conform to the Uniform System of Accounts as prescribed by the Federal Energy Regulatory Commission (FERC).  Chugach meets the criteria, and accordingly, follows the accounting and reporting requirements of Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 980, “Topic 980 - Regulated Operations.”  FASB ASC 980 provides for the recognition of regulatory assets and liabilities as allowed by regulators for costs or credits that are reflected in current rates or are considered probable of being included in future rates.  Our regulated rates are established to recover all of our specific costs of providing electric service.  In each rate filing, rates are set at levels to recover all of our specific allowable costs and those rates are then collected from our retail and wholesale customers.  The regulatory assets or liabilities are then reduced as the cost or credit is reflected in earnings and our rates, see Note (2j) – “Deferred Charges and Credits.”
Utility Plant And Depreciation	'
	c. Utility Plant and Depreciation
	Additions to electric plant in service are recorded at original cost of contracted services, direct labor and materials, indirect overhead charges and capitalized interest.  For property replaced or retired, the book value of the property, less salvage, is charged to accumulated depreciation.  The removal cost is charged to cost of removal obligation.  Renewals and betterments are capitalized, while maintenance and repairs are normally charged to expense as incurred.
	In accordance with FASB ASC 360, “Topic 360 – Property, Plant, and Equipment,” certain asset groups are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset group may not be recoverable in rates.  Recoverability of asset groups to be held and used is measured by a comparison of the carrying amount of an asset group to estimated undiscounted future cash flows expected to be generated by the asset group.  If the carrying amount of an asset group exceeds its estimated future cash flows, an impairment charge is recognized by the amount by which the carrying amount of the asset group exceeds the fair value of the asset.
	Depreciation and amortization rates have been applied on a straight‑line basis and at December 31, 2013 are as follows:
	Annual Depreciation Rate Ranges
	Steam production plant	4.81%	-	7.04%
	Hydraulic production plant	1.06%	-	3.00%
	Other production plant	3.98%	-	10.15%
	Transmission plant	1.58%	-	7.86%
	Distribution plant	2.17%	-	9.63%
	General plant	1.57%	-	20.00%
	Other	2.75%	-	2.75%
	Southcentral Power Project (SPP) steam production plant	3.09%	-	3.46%
	SPP other production plant	3.15%	-	3.84%
	On November 1, 2010, the RCA approved revised depreciation rates effective November 1, 2010 in Docket U-09-097.  Chugach’s depreciation rates include a provision for cost of removal.
	Chugach records a separate liability for the estimated obligation related to the cost of removal.
	On August 31, 2012, in Docket U-12-009, the RCA approved SPP depreciation rates effective February 1, 2013, the date the SPP plant was placed in service.
Capitalized Interest	'
	d. Capitalized Interest
	Allowance for funds used during construction (AFUDC) and interest charged to construction ‑ credit (IDC) are the estimated costs of the funds used during the period of construction from both equity and borrowed funds.  AFUDC and IDC are applied to specific projects during construction.  AFUDC and IDC calculations use the net cost of borrowed funds when used and is recovered through RCA approved rates as utility plant is depreciated.  For all projects excluding SPP, Chugach capitalized such funds at the weighted average rate (adjusted monthly) of 3.7 percent during 2013, 4.0 percent during 2012 and 4.1 percent during 2011.  For SPP, Chugach capitalized actual interest expense and related fees associated with its construction.
Investments In Associated Organizations	'
	e. Investments in Associated Organizations
	The loan agreements with CoBank, ACB (CoBank) and National Rural Utilities Cooperative Finance Corporation (NRUCFC) requires as a condition of the extension of credit, that an equity ownership position be established by all borrowers.  Chugach’s equity ownership in these organizations is less than 1 percent.  These investments are non-marketable and accounted for at cost.  Management evaluates these investments annually for impairment.  No impairment was recorded during 2013, 2012 and 2011.
Fair Value Of Financial Instruments	'
	f. Fair Value of Financial Instruments
	FASB ASC 825, “Topic 825 – Financial Instruments,” requires disclosure of the fair value of certain on and off balance sheet financial instruments for which it is practicable to estimate that value.  The following methods are used to estimate the fair value of financial instruments:
	Cash and cash equivalents ‑ the carrying amount approximates fair value because of the short maturity of those instruments.
	Consumer deposits ‑ the carrying amount approximates fair value because of the short refunding term.
	Long‑term obligations ‑ the fair value is estimated based on the quoted market price for same or
	similar issues (see note 11).
	Restricted cash – the carrying amount approximates fair value because of the short maturity of those instruments.
	Repurchase agreement – the carrying amount approximates fair value because of the short maturity of those instruments.
Cash And Cash Equivalents / Restricted Cash Equivalents	'
	g. Cash and Cash Equivalents / Restricted Cash Equivalents
	For purposes of the statement of cash flows, Chugach considers all highly liquid instruments with a maturity of three months or less upon acquisition by Chugach to be cash equivalents.  In November of 2011, Chugach opened a concentration account with First National Bank Alaska (FNBA).  There is no rate of return or fees on this account.  On December 30, 2011, Chugach opened a money market account with UBS Financial Services, Inc. (UBS) with an initial deposit of $10.0 million, which was subsequently invested in marketable securities in September of 2012.  Chugach also maintains an Overnight Repurchase Agreement with FNBA, however, in November of 2011 this account was placed into an inactive status.  The concentration account had an average balance of $6,262,978 and $8,942,631 for the years ended December 31, 2013 and 2012, respectively.
	On January 12, 2012, Chugach opened a money market account with KeyBank with the balance of proceeds from the 2012 Series A bond purchase, after repaying the outstanding balance of commercial paper.  Chugach’s initial deposit was $69.0 million.  Chugach used the proceeds primarily to fund capital expenditures associated with SPP and closed the account in February of 2013.
	Restricted cash equivalents include funds on deposit for future workers compensation claims and interim rates collected from customers and escrowed as required by the RCA.
Accounts Receivable	'
	h. Accounts Receivable
	Trade accounts receivable are recorded at the invoiced amount.  The allowance for doubtful accounts is management’s best estimate of the amount of probable credit losses in existing accounts receivable.  Chugach determines the allowance based on its historical write-off experience and current economic conditions.  Chugach reviews its allowance for doubtful accounts monthly.  Past due balances over 90 days in a specified amount are reviewed individually for collectability.  All other balances are reviewed in aggregate.  Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote.  Chugach does not have any off–balance-sheet credit exposure related to its customers. Included in accounts receivable are invoiced amounts to ML&P for their proportionate share of current SPP costs, which amounted to $1.8 and $3.0 million in 2013 and 2012, respectively.  In addition, accounts receivable includes invoiced amounts for grants to support the construction of facilities to divert water and safely transmit electricity, which amounted to $2.8 million in 2013 and $4.0 million in 2012.
Materials And Supplies	'
	i. Materials and Supplies
	Materials and supplies are stated at average cost.
Deferred Charges and Credits	'
	j. Deferred Charges and Credits
	In accordance with FASB ASC 980, Chugach’s financial statements reflect regulatory assets and liabilities.  Continued accounting under FASB ASC 980, requires that certain criteria be met. We capitalize all or part of costs that would otherwise be charged to expense if it is probable that future revenue in an amount at least equal to the capitalized cost will result from inclusion of that cost in allowable costs for ratemaking purposes and future revenue will be provided to permit recovery of the previously incurred cost.  Management believes Chugach’s operations currently satisfy these criteria.
	Chugach regulatory asset recoveries are embedded in base rates approved by the RCA.  Specific costs incurred and recorded as Regulatory Assets, including the amortization period for recovery, are approved by the RCA either in standard Simplified Rate Filings (SRF), general rate case filings or specified independent requests.  The rates approved related to the regulatory assets are matched to the amortization of actual expenses recognized. The regulatory assets are amortized and collected through rates over differing periods depending upon the period of benefit as established by the RCA.  Deferred credits, primarily representing regulatory liabilities, are amortized to operating expense over the period required for ratemaking purposes.  It also includes refundable contributions in aid of construction, which are credited to the associated cost of construction of property units.  Refundable contributions in aid of construction are held in deferred credits pending their return or other disposition.  If events or circumstances should change so the criteria are not met, the write off of regulatory assets and liabilities could have a material effect on Chugach’s financial position or results of operations.
Patronage Capital	'
	k. Patronage Capital
	Revenues in excess of current period costs (net operating margins and nonoperating margins) in any year are designated on Chugach's statement of revenues and expenses as assignable margins. These excess amounts (i.e. assignable margins) are considered capital furnished by the members, and are credited to their accounts and held by Chugach until such future time as they are retired and returned without interest at the discretion of the Board of Directors (Board).  Retained assignable margins are designated on Chugach's balance sheet as patronage capital.  This patronage capital constitutes the principal equity of Chugach.  The Board may also approve the return of capital to former members and estates who request early retirements at discounted rates under a discounted capital credits retirement plan authorized by the Board in September of 2002.
	In 2007, Chugach entered into an agreement with HEA to return all of its patronage capital within five years after expiration of its power sales agreement, which is December 31, 2013.  This patronage capital retirement was related to a settlement agreement associated with the 2005 Test Year General Rate Case (Docket U-06-134).  The RCA accepted the parties’ settlement agreement on August 9, 2007.  HEA’s patronage capital is classified as patronage capital payable and was $7.9 million at December 31, 2013.
Operating Revenues	'
	l. Operating Revenues
	Revenues are recognized upon delivery of electricity.  Operating revenues are based on billing rates authorized by the RCA, which are applied to customers' usage of electricity.  Chugach’s rates are established, in part, on test period sales levels that reflect actual operating results.  Chugach calculates unbilled revenue at the end of each month to ensure the recognition of a calendar year’s revenue.  Chugach accrued $9,274,135 and $8,548,660 of unbilled retail revenue at December 31, 2013 and 2012, respectively. Wholesale revenue is recorded from metered locations on a calendar month basis, so no estimation is required.  Chugach's tariffs include provisions for the recovery of gas costs according to gas supply contracts, as well as purchased power costs.
Fuel And Purchased Power Costs Recovery	'
	m. Fuel and Purchased Power Costs Recovery
	Expenses associated with electric services include fuel used to generate electricity and power purchased from others.  Chugach is authorized by the RCA to recover fuel and purchased power costs through the fuel and purchased power adjustment process, which is adjusted quarterly to reflect increases and decreases of such costs.  We recognize differences between projected recoverable fuel costs and amounts actually recovered through rates.  The fuel cost under/over recovery on our Balance Sheet represents the net accumulation of any under- or over-collection of fuel and purchase power costs.  Fuel cost under-recovery will appear as an asset on our Balance Sheet and will be collected from our members in subsequent periods.  Conversely, fuel cost over-recovery will appear as a liability on our Balance Sheet and will be refunded to our members in subsequent periods.  Fuel costs were over-recovered by $1,635,677 in 2013 and over-recovered by $13,710,049 in 2012.  Total fuel and purchased power costs in 2013, 2012, and 2011 were $164,446,942, $147,941,346, and $165,041,227, respectively.
Environmental Remediation Costs	'
	n. Environmental Remediation Costs
	Chugach accrues for losses and establishes a liability associated with environmental remediation obligations when such losses are probable and can be reasonably estimated.  Such accruals are adjusted as further information develops or circumstances change.   Estimates of future costs for environmental remediation obligations are not discounted to their present value. However, various remediation costs may be recoverable through rates and accounted for as a regulatory
	asset.
Income Taxes	'
	o. Income Taxes
	Chugach is exempt from federal income taxes under the provisions of Section 501(c)(12) of the Internal Revenue Code and for the years ended December 31, 2013, 2012 and 2011 was in compliance with that provision.  In addition, as described in “Note (15) - Commitments and Contingencies,” Chugach collects sales tax and is assessed gross receipts and excise taxes which are presented on a net basis in accordance with FASB ASC 605-45-50, “Topic 605 - Revenue Recognition – Subtopic 45 - Principal Agent Considerations – Section 50 - Disclosure.”
	(2)    Significant Accounting Policies (continued)
	o. Income Taxes (continued)
	Chugach applies a more-likely-than-not recognition threshold for all tax uncertainties.  FASB ASC 740, “Topic 740 – Income Taxes,” only allows the recognition of those tax benefits that have a greater than 50 percent likelihood of being sustained upon examination by the taxing authorities.  Chugach’s management reviewed Chugach’s tax positions and determined there were no outstanding, or retroactive tax positions, that were not highly certain of being sustained upon examination by the taxing authorities.
	Management has concluded that there are no significant uncertain tax positions requiring recognition in its financial statements for all periods presented.  Chugach’s evaluation was performed for the tax periods ended December 31, 2010 through December 31, 2013 for United States Federal Income Tax, the tax years which remain subject to examination by major tax jurisdictions as of December 31, 2013.
Consumer Deposits	'
	p. Consumer deposits
	Consumer deposits are the amounts certain customers are required to deposit to receive electric service.  Consumer deposits for the years ended December 31, 2013 and 2012, totaled $2.5 million and $2.4 million, respectively.  Consumer deposits also represent customer credit balances as a result of prepaid accounts.  Credit balances for the years ended December 31, 2013 and 2012 totaled $2.4 million and $1.9 million, respectively.
Grants	'
	q. Grants
	Chugach has received federal and state grants to offset storm related expenditures and to support the construction of facilities to transport fuel, divert water and safely transmit electricity to its consumers.  Grant proceeds used to construct or acquire equipment are offset against the carrying amount of the related assets while grant proceeds for storm related expenditures are offset against the actual expense incurred, which totaled $17.4 million and $30.5 million in 2013 and 2012, respectively.  The assets constructed from grant awards may not be sold, or used as collateral for any reason.
Fuel Stock	'
	r. Fuel Stock
	Fuel Stock is the weighted average cost of fuel injected into the Cook Inlet Natural Gas Storage Alaska (CINGSA), which began service in the second quarter of 2012.  Chugach’s fuel balance in storage for the years ended December 31, 2013 and 2012 amounted to $13.0 million and $9.5 million, respectively.
Marketable Securities	'
	s. Marketable Securities
	In September of 2012, Chugach implemented a bond and equity investment portfolio.  Chugach’s initial investment was $10.0 million.  The investments are classified as marketable securities, reported at fair value with gains and losses included in earnings.  At December 31, 2013 and 2012, the carrying amount and fair value was $10.3 million and $10.1 million, respectively.
Reclassifications	'
	t. Reclassifications
	For the year ended December 31, 2013, Chugach recorded the following reclassification for the year ended December 31, 2012:
	A reclassification representing the expected future cost of removal of our regulated assets previously included as an increase in accumulated depreciation and now included as an increase in cost of removal obligations. The impact of the reclassification was to decrease accumulated depreciation and increase cost of removal obligations by $44.6 million in 2012.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Significant Accounting Policies [Abstract]	'
Schedule Of Depreciation And Amortization Rates	'
	Steam production plant	4.81%	-	7.04%
	Hydraulic production plant	1.06%	-	3.00%
	Other production plant	3.98%	-	10.15%
	Transmission plant	1.58%	-	7.86%
	Distribution plant	2.17%	-	9.63%
	General plant	1.57%	-	20.00%
	Other	2.75%	-	2.75%
	Southcentral Power Project (SPP) steam production plant	3.09%	-	3.46%
	SPP other production plant	3.15%	-	3.84%

Fair_Values_Of_Assets_And_Liab1

Fair Values Of Assets And Liabilities (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Values Of Assets And Liabilities [Abstract]	'
Schedule Of Assets Measured At Fair Value On A Recurring Basis	'
			Total		Level 1		Level 2		Level 3
	31-Dec-13
	Marketable securities	$	10,308,533	$	10,308,533	$	0	$	0
	31-Dec-12
	Money market	$	2,829,397	$	2,829,397	$	0	$	0
	Marketable securities	$	10,158,016	$	10,158,016	$	0	$	0

Utility_Plant_Tables

Utility Plant (Tables)	12 Months Ended
	Dec. 31, 2013
Utility Plant [Abstract]	'
Schedule Of Major Classes Of Utility Plant	'
	Electric plant in service:	2013		2012
	Steam production plant	$	60,462,671	$	60,462,671
	Hydraulic production plant		20,546,809		20,513,746
	Other production plant		122,051,709		127,980,607
	Transmission plant		249,483,480		252,910,740
	Distribution plant		258,474,600		257,587,220
	General plant		48,517,709		51,901,426
	Unclassified electric plant in service1		369,280,657		109,023,464
	Intangible plant1		4,710,912		4,710,912
	Other1		1,828,409		6,690,723
	Total electric plant in service		1,135,356,956		891,781,509
	Construction work in progress2		28,674,163		263,459,794
	Total electric plant in service and construction work in progress	$	1,164,031,119	$	1,155,241,303
	1Unclassified electric plant in service consists of complete unclassified general plant, generation plant, transmission plant and distribution plant.  Depreciation of unclassified electric plant in service has been included in functional plant depreciation accounts in accordance with the anticipated eventual classification of the plant investment.  Intangible plant represents Chugach's share of a Bradley Lake transmission line financed internally.  Other represents Electric Plant Held for Future Use.
	2The amount associated with the construction of SPP included in construction work in progress was $245.5 million at December 31, 2012.

Investments_In_Associated_Orga1

Investments In Associated Organizations (Tables)	12 Months Ended
	Dec. 31, 2013
Investments In Associated Organizations [Abstract]	'
Schedule Of Investments In Associated Organizations	'
		2013		2012
	NRUCFC	$	6,095,980	$	6,095,980
	CoBank		4,044,338		4,392,948
	NRUCFC Capital Term Certificates and other		63,875		63,755
	Total investments in associated organizations	$	10,204,193	$	10,552,683

Deferred_Charges_And_Credits_T

Deferred Charges And Credits (Tables)	12 Months Ended
	Dec. 31, 2013
Regulatory Assets And Liabilities [Line Items]	'
Schedule Of Deferred Charges Or Regulatory Assets	'
		2013		2012
	Debt issuance and reacquisition costs	$	3,611,498	$	4,126,529
	Refurbishment of transmission equipment		132,717		141,976
	Feasibility studies		912,537		76,390
	Beluga gas compression		1,526,599		2,035,466
	Cooper Lake relicensing / projects		5,670,314		5,800,417
	Fuel supply negotiations		971,209		815,451
	Major overhaul of steam generating unit		1,285,942		1,510,046
	Other regulatory deferred charges		1,759,448		4,473,037
	Bond interest - market risk management		6,960,044		7,527,357
	Environmental matters and other		1,160,223		1,205,574
	Total deferred charges	$	23,990,531	$	27,712,243
Schedule Of Deferred Credits Or Regulatory Liabilities	'
		2013		2012
	Refundable consumer advances for construction	$	773,089	$	777,323
	Estimated initial installation costs for meters		104,037		92,149
	Post retirement benefit obligation		899,700		899,700
	Total deferred costs	$	1,776,826	$	1,769,172
Not Currently Being Recovered In Rates Charged to Consumers [Member]	'
Regulatory Assets And Liabilities [Line Items]	'
Schedule Of Deferred Charges Or Regulatory Assets	'
		2013		2012
	Fuel supply (negotiations/studies/compression)	$	231,712	$	1,072,002
	Studies and other		336,017		236,401
	Wind project		34,543		391,285
	Financing related costs		0		1,757,624
	Beluga Unit 8 inspection		0		1,061,838
	Total deferred charges	$	602,272	$	4,519,150

Other_Equities_Tables

Other Equities (Tables)	12 Months Ended
	Dec. 31, 2013
Other Equities [Abstract]	'
Schedule Of Other Equities	'
		2013		2012
	Nonoperating margins, prior to 1967	$	23,625	$	23,625
	Donated capital		1,742,889		1,647,869
	Unclaimed capital credit retirement1		9,679,404		9,700,861
	Total other equities	$	11,445,918	$	11,372,355
	1Represents unclaimed capital credits that have met all requirements of section 34.45.200 of Alaska’s    unclaimed property law and has therefore reverted to Chugach

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt [Abstract]	'
Schedule Of Long-Term Debt Obligations	'
	Long-term obligations at December 31 are as follows:	2013			2012
	CoBank 3 and 4, 2.52% variable rate notes maturing in 2022, with interest payable monthly and principal due annually beginning in 2003	$	29,680,420		$	31,756,775
	2011 Series A Bond of 4.20%, maturing in 2031, with interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012		81,000,000			85,500,000
	2011 Series A Bond of 4.75%, maturing in 2041, with interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012		172,666,666			178,833,333
	2012 Series A Bond of 4.01%, maturing in 2032, with interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2013		71,250,000			75,000,000
	2012 Series A Bond of 4.41%, maturing in 2042, with interest payable semi-annually March 15 and September 15 and principal due annually between 2013 and 2020 and between 2032 and 2042		117,000,000			125,000,000
	2012 Series A Bond of 4.78%, maturing in 2042, with interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2023		50,000,000			50,000,000
	Total long-term obligations	$	521,597,086		$	546,090,108
	Less current installments		24,682,812			24,493,022
	Long-term obligations, excluding current installments	$	496,914,274		$	521,597,086
Schedule Of Maturities Of Long-Term Debt Obligations	'
	Year ending			2011 Series A			CoBank Note		2012 Series A			Total
	31-Dec			Bonds					Bonds
	2014			10,666,667			2,266,145		11,750,000			24,682,812
	2015			10,666,667			2,473,110		10,750,000			23,889,777
	2016			10,666,667			2,699,313		10,750,000			24,115,980
	2017			10,666,667			2,945,954		10,750,000			24,362,621
	2018			10,666,667			3,215,267		10,750,000			24,631,934
	Thereafter			200,333,331			16,080,631		183,500,000			399,913,962
			$	253,666,666		$	29,680,420	$	238,250,000		$	521,597,086
Schedule Of Average Commercial Paper Balances Outstanding And Weighted Average Interest Rates	'
	Month		Average		Weighted Average		Month	Average		Weighted Average
			Balance		Interest Rate			Balance		Interest Rate
	January		$5.90		0.27		July	$33.40		0.23
	February		$0.10		0.25		August	$35.00		0.21
	March		$23.20		0.29		September	$42.10		0.21
	April		$40.00		0.26		October	$49.90		0.23
	May		$39.70		0.24		November	$52.70		0.19
	June		$34.30		0.24		December	$53.10		0.2
Schedule Of Carrying Values And Estimated Fair Values Of Long-Term Debt Obligations	'
		Carrying Value			Fair Value
	Long-term obligations (including current installments)	$	521,597		$	512,435

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2013
Employee Benefit Plans [Abstract]	'
Schedule Of Information For Significant Pension Plans	'
		Alaska Electrical Pension Plan3			NRECA Retirement Security Plan3
	Employer Identification Number	92-6005171			53-0116145
	Plan Number	1			333
	Year-end Date	31-Dec			31-Dec
	Expiration Date of CBA's	30-Jun-17			N/A2
	Subject to Funding Improvement Plan	No			No4
	Surcharge Paid	N/A			N/A4
		2013	2012	2011	2013	2012	2011
	Zone Status	Green	Green	Green	N/A1	N/A1	N/A1
	Required minimum contributions	None	None	None	N/A	N/A	N/A
	Contributions (in millions)	$3.40	$3.60	$3.00	$3.40	$3.00	$3.00
	Contributions > 5% of total plan contributions	Yes	Yes	Yes	No	No	No
	1A “zone status” determination is not required, and therefore not determined under the Pension Protection Act (PPA) of 2006.
	2The CEO is the only non-union employee subject to an employment agreement, which is effective through July 17, 2016.
	3The Alaska Electrical Pension Plan is publicly available.  The NRECA Retirement Security Plan is available on Chugach’s website at www.chugachelectric.com.
	4The provisions of the PPA do not apply to the RS Plan, therefore, funding improvement plans and surcharges are not applicable.  Future contribution requirements are determined each year as part of the actuarial valuation of the RS Plan and may change as a result of plan experience.

Bradley_Lake_Hydroelectric_Pro1

Bradley Lake Hydroelectric Project (Tables)	12 Months Ended
	Dec. 31, 2013
Bradley Lake Hydroelectric Project [Abstract]	'
Bradley Lake Project Financials	'
	(In thousands)	Total	Proportionate Share
	Plant in service	$177,968	$54,102
	Long-term debt	80,117	24,356
	Interest expense	4,618	1,404

Commitments_And_Contingencies_

Commitments And Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments And Contingencies [Abstract]	'
Schedule Of Costs Of Fuel Purchased And Transported As A Percentage Of Total Fuel Costs	'
		2013	2012	2011
	Marathon Oil Company	4.50%	72.00%	44.90%
	Chevron / Unocal / Hilcorp	46.40%	1.30%	16.10%
	ML&P	0.00%	0.00%	3.60%
	ConocoPhillips (COP)	42.80%	24.20%	31.90%
	ENSTAR	2.10%	2.20%	1.30%
	Hilcorp Pipeline	3.80%	0.00%	0.00%
	Miscellaneous	0.40%	0.30%	2.20%

Quarterly_Results_Of_Operation1

Quarterly Results Of Operations (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Results Of Operations (Unaudited) [Abstract]	'
Schedule Of Quarterly Results Of Operations	'
	2013 Quarter Ended
		Dec. 31		Sept. 30		30-Jun		31-Mar
	Operating Revenue	$	81,068,132	$	71,715,353	$	74,776,425	$	77,748,517
	Operating Expense		73,756,307		67,061,684		70,076,488		67,844,018
	Net Interest		6,014,808		6,016,792		6,058,246		5,291,626
	Net Operating Margins		1,297,017		-1,363,123		-1,358,309		4,612,873
	Nonoperating Margins		6,918,314		226,803		-18,235		228,703
	Assignable Margins	$	8,215,331	$	-1,136,320	$	-1,376,544	$	4,841,576
	2012 Quarter Ended
		Dec. 31		Sept. 30		30-Jun		31-Mar
	Operating Revenue	$	74,483,455	$	62,675,511	$	58,631,729	$	71,180,773
	Operating Expense		68,250,215		60,200,529		55,725,151		64,019,060
	Net Interest		3,492,044		3,495,865		3,542,676		3,872,346
	Net Operating Margins		2,741,196		-1,020,883		-636,098		3,289,367
	Nonoperating Margins		632,775		261,487		123,962		133,701
	Assignable Margins	$	3,373,971	$	-759,396	$	-512,136	$	3,423,068

Description_Of_Business_Detail

Description Of Business (Details)	12 Months Ended
	Dec. 31, 2013
	customer
	mi
Description Of Business [Abstract]	'
Electrification area	400
Number of wholesale customers	2

Significant_Accounting_Policie3

Significant Accounting Policies (Narrative) (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Mar. 31, 2011

Dec. 30, 2011

Dec. 31, 2013

Dec. 31, 2012

Jan. 12, 2012

CoBank, ACB (CoBank) And National Rural Utilities Cooperative Finance Corporation (NRUCFC) [Member]

Fair Value [Member]

Fair Value [Member]

Unbilled Retail Revenues [Member]

Unbilled Retail Revenues [Member]

ML&P For Fuel and South Central Power Project Costs [Member]

ML&P For Fuel and South Central Power Project Costs [Member]

Alaska Energy Authority For Grant [Member]

Alaska Energy Authority For Grant [Member]

Homer Electric Association, Inc. [Member]

Homer Electric Association, Inc. [Member]

Homer Electric Association, Inc. [Member]

UBS Financial Services [Member]

Concentration Account [Member]

Concentration Account [Member]

Key Bank [Member]

Maximum [Member]

Significant Accounting Policies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average capital interest percentage

3.70%

4.00%

4.10%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost ownership percentage

'

'

'

'

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Impairment on investments

$0

$0

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Money market

'

2,829,397

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

'

69,000,000

Average balance of cash account

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,262,978

8,942,631

'

Minimum number of days past balances reviewed

'90 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of years to return patronage capital after expiration of power agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

Patronage capital payable

7,931,295

6,858,367

'

'

'

'

'

'

'

'

'

'

'

7,900,000

6,900,000

6,500,000

'

'

'

'

Accounts receivable

44,633,981

46,650,901

'

'

'

'

'

9,274,135

8,548,660

1,800,000

3,000,000

2,800,000

4,000,000

'

'

'

'

'

'

'

Fuel cost over-recovery

1,635,677

13,710,049

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fuel and purchased power costs

164,446,942

147,941,346

165,041,227

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consumer deposits

2,500,000

2,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Customer credits

2,400,000

1,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Grant proceeds included in public utilities property plant and equipment carry value

17,400,000

30,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fuel stock

13,029,848

9,466,767

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Marketable securities

10,308,533

10,158,016

'

10,000,000

'

10,300,000

10,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase in cost of removal obligations

'

($44,600,000)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Significant_Accounting_Policie4

Significant Accounting Policies (Schedule Of Depreciation Rates) (Details)	12 Months Ended
	Dec. 31, 2013
Minimum [Member] | Steam Production Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	4.81%
Minimum [Member] | Hydraulic Production Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	1.06%
Minimum [Member] | Other Production Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	3.98%
Minimum [Member] | Transmission Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	1.58%
Minimum [Member] | Distribution Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	2.17%
Minimum [Member] | General Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	1.57%
Minimum [Member] | Other Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	2.75%
Minimum [Member] | Southcentral Power Project (SPP) Steam Production Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	3.09%
Minimum [Member] | SPP Other Production Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	3.15%
Maximum [Member] | Steam Production Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	7.04%
Maximum [Member] | Hydraulic Production Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	3.00%
Maximum [Member] | Other Production Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	10.15%
Maximum [Member] | Transmission Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	7.86%
Maximum [Member] | Distribution Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	9.63%
Maximum [Member] | General Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	20.00%
Maximum [Member] | Other Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	2.75%
Maximum [Member] | Southcentral Power Project (SPP) Steam Production Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	3.46%
Maximum [Member] | SPP Other Production Plant [Member]	'
Public Utility, Property, Plant and Equipment [Line Items]	'
Depreciation and amortization rate	3.84%

Fair_Values_Of_Assets_And_Liab2

Fair Values Of Assets And Liabilities (Schedule Of Assets Measured At Fair Value On A Recurring Basis) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Sep. 30, 2012
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Money market	'	$2,829,397	'
Marketable securities	10,308,533	10,158,016	10,000,000
Level 1 [Member]	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Money market	'	2,829,397	'
Marketable securities	10,308,533	10,158,016	'
Level 2 [Member]	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Money market	'	0	'
Marketable securities	0	0	'
Level 3 [Member]	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Money market	'	0	'
Marketable securities	$0	$0	'

Regulatory_Matters_Details

Regulatory Matters (Details) (USD $)

0 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Nov. 19, 2013

Oct. 23, 2013

Dec. 12, 2012

Dec. 31, 2013

Dec. 27, 2013

Dec. 10, 2013

Jan. 02, 2014

Feb. 06, 2013

Jan. 02, 2014

Jan. 02, 2014

Feb. 06, 2013

Feb. 06, 2013

Jul. 31, 2013

Dec. 31, 2013

Mar. 31, 2018

Dec. 31, 2017

Jul. 12, 2013

Sep. 30, 2013

Dec. 31, 2013

Retail Customers [Member]

Retail Customers [Member]

Matanuska Electric Association, Inc. [Member]

Seward [Member]

Minimum [Member]

Maximum [Member]

Hilcorp Alaska, LLC [Member]

Hilcorp Alaska, LLC [Member]

Hilcorp Alaska, LLC [Member]

Hilcorp Alaska, LLC [Member]

Hilcorp Alaska, LLC [Member]

Cook Inlet Energy, LLC [Member]

Cook Inlet Energy, LLC [Member]

Wholesale Customers [Member]

Wholesale Customers [Member]

Forecast [Member]

Forecast [Member]

Forecast [Member]

MMcf

Regulatory Matters [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proposed increase (decrease) in base rate revenue

$16

($0.20)

$30

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proposed percentage increase decrease in base rate revenue

12.50%

-0.10%

26.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Base rate revenue for proposed rate increase (decrease)

127.4

143

115

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase (decrease) in system demand and energy rate

'

'

'

'

'

'

6.00%

6.00%

8.00%

5.00%

4.00%

7.00%

'

'

'

'

'

'

'

Amortization period of storm related costs

'

'

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

State statutory interest rate on refundable deposits not in escrow

'

'

'

10.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Petitioned retention of escrowed funds

'

'

'

'

'

0.5

'

'

'

'

'

'

'

'

'

'

'

'

'

Refunds to be covered under settlement

'

'

'

'

$0.20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated amount of gas under contract

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,700

'

'

Percentage of unmet natural gas need

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

100.00%

'

'

'

Contract time period

'

'

'

'

'

'

'

'

'

'

'

'

'January 1, 2015, through March 31, 2018

'

'

'

'

'April 1, 2014, and terminating on March 31, 2018

'

Description of natural gas contract

'

'

'

'

'

'

'

'

'

'

'

'

'The new agreement is designed to fill the balance of Chugach's unmet needs in 2015 and 2016, up to 100% of unmet needs in 2017 and up to 100% of its total needs in the first quarter of 2018

'

'

'

'

'

'

Commencement date of long term contract for purchase of gas supply

'

'

'

'

'

'

'

'

'

'

'

'

'

1-Jan-15

'

'

'

'

1-Apr-14

Expiration date of long term contract for purchase of gas supply

'

'

'

'

'

'

'

'

'

'

'

'

'

31-Mar-18

'

'

'

'

31-Mar-18

Utility_Plant_Schedule_Of_Majo

Utility Plant (Schedule Of Major Classes Of Utilty Plant) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
Public Utility, Property, Plant and Equipment [Line Items]	'		'
Total electric plant in service	$1,135,356,956		$891,781,509
Construction work in progress	28,674,163	[1]	263,459,794	[1]
Total utility plant	1,164,031,119		1,155,241,303
Steam Production Plant [Member]	'		'
Public Utility, Property, Plant and Equipment [Line Items]	'		'
Generation and processing	60,462,671		60,462,671
Hydraulic Production Plant [Member]	'		'
Public Utility, Property, Plant and Equipment [Line Items]	'		'
Generation and processing	20,546,809		20,513,746
Other Production Plant [Member]	'		'
Public Utility, Property, Plant and Equipment [Line Items]	'		'
Generation and processing	122,051,709		127,980,607
Transmission Plant [Member]	'		'
Public Utility, Property, Plant and Equipment [Line Items]	'		'
Transmission	249,483,480		252,910,740
Distribution Plant [Member]	'		'
Public Utility, Property, Plant and Equipment [Line Items]	'		'
Distribution	258,474,600		257,587,220
General Plant [Member]	'		'
Public Utility, Property, Plant and Equipment [Line Items]	'		'
Other property, plant and equipment	48,517,709		51,901,426
Unclassified Electric Plant [Member]	'		'
Public Utility, Property, Plant and Equipment [Line Items]	'		'
Other property, plant and equipment	369,280,657	[2]	109,023,464	[2]
Intangible Plant [Member]	'		'
Public Utility, Property, Plant and Equipment [Line Items]	'		'
Transmission	4,710,912	[2]	4,710,912	[2]
Other [Member]	'		'
Public Utility, Property, Plant and Equipment [Line Items]	'		'
Other- land	1,828,409	[2]	6,690,723	[2]
Southcentral Power Project [Member]	'		'
Public Utility, Property, Plant and Equipment [Line Items]	'		'
Construction work in progress	'		$245,500,000
[1]	The amount associated with the construction of SPP included in construction work in progress was $245.5 million at December 31, 2012.
[2]	Unclassified electric plant in service consists of complete unclassified general plant, generation plant, transmission plant and distribution plant. Depreciation of unclassified electric plant in service has been included in functional plant depreciation accounts in accordance with the anticipated eventual classification of the plant investment. Intangible plant represents Chugach's share of a Bradley Lake transmission line financed internally. Other represents Electric Plant Held for Future Use.

Investments_In_Associated_Orga2

Investments In Associated Organizations (Schedule Of Investments In Associated Organizations) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Schedule of Cost-method Investments [Line Items]	'	'
Investments in associated organizations	$10,204,193	$10,552,683
National Rural Utilities Cooperative Finance Corporation (NRUCFC) [Member]	'	'
Schedule of Cost-method Investments [Line Items]	'	'
Investments in associated organizations	6,095,980	6,095,980
CoBank, ACB [Member]	'	'
Schedule of Cost-method Investments [Line Items]	'	'
Investments in associated organizations	4,044,338	4,392,948
NRUCFC Capital Term Certificates And Other [Member]	'	'
Schedule of Cost-method Investments [Line Items]	'	'
Investments in associated organizations	$63,875	$63,755

Deferred_Charges_And_Credits_S

Deferred Charges And Credits (Schedule Of Regulatory Assets)(Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Regulatory Assets [Line Items]	'	'
Total deferred charges	$23,990,531	$27,712,243
Debt Issuance And Reacquisition Costs [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	3,611,498	4,126,529
Refurbishment Of Transmission Equipment [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	132,717	141,976
Feasibility Studies [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	912,537	76,390
Beluga Gas Compression [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	1,526,599	2,035,466
Cooper Lake Relicensing / Projects [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	5,670,314	5,800,417
Fuel Supply Negotiations [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	971,209	815,451
Major Overhaul Of Steam Generating Unit [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	1,285,942	1,510,046
Other Regulatory Deferred Charges [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	1,759,448	4,473,037
Bond Interest - Market Risk Management [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	6,960,044	7,527,357
Environmental Matters And Other [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	$1,160,223	$1,205,574

Deferred_Charges_And_Credits_S1

Deferred Charges And Credits (Schedule Of Regulatory Assets Not Currently Being Recovered In Rates Charged To Consumers) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Regulatory Assets [Line Items]	'	'
Total deferred charges	$23,990,531	$27,712,243
Not Currently Being Recovered In Rates Charged to Consumers [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	602,272	4,519,150
Not Currently Being Recovered In Rates Charged to Consumers [Member] | Other Regulatory Deferred Charges (Fuel Supply (Negotiations/Studies/Compression)) [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	231,712	1,072,002
Not Currently Being Recovered In Rates Charged to Consumers [Member] | Other Regulatory Deferred Charges (Studies / Other) [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	336,017	236,401
Not Currently Being Recovered In Rates Charged to Consumers [Member] | Other Regulatory Deferred Charges (Wind Project) [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	34,543	391,285
Not Currently Being Recovered In Rates Charged to Consumers [Member] | Bond Interest - Market Risk Management (Financing Related Costs) [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	0	1,757,624
Not Currently Being Recovered In Rates Charged to Consumers [Member] | Other Regulatory Deferred Charges (Beluga Unit 8 Inspection) [Member]	'	'
Regulatory Assets [Line Items]	'	'
Total deferred charges	$0	$1,061,838

Deferred_Charges_And_Credits_S2

Deferred Charges And Credits (Schedule Of Regulatory Liabilities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Regulatory Liabilities [Line Items]	'	'
Deferred costs	$1,776,826	$1,769,172
Refundable Consumer Advances For Construction[Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Deferred costs	773,089	777,323
Estimated Initial Installation Costs Of Meters [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Deferred costs	104,037	92,149
Post Retirement Benefit Obligation [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Deferred costs	$899,700	$899,700

Patronage_Capital_Details

Patronage Capital (Details) (USD $)

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Mar. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2013

Excluding Homer Electric Association Retirement [Member]

Excluding Homer Electric Association Retirement [Member]

Excluding Homer Electric Association Retirement [Member]

Excluding Homer Electric Association Retirement [Member]

Assignable Margins [Member]

Homer Electric Association, Inc. [Member]

Homer Electric Association, Inc. [Member]

Homer Electric Association, Inc. [Member]

Homer Electric Association, Inc. [Member]

Minimum [Member]

Patronage Capital Distribution [Member]

Aggregate Equities And Margins To Total Liabilities And Equities And Margins [Member]

Patronage Capital [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Patronage capital

$162,749,889

$153,832,674

'

'

'

'

'

'

'

'

'

$6,500,000

'

'

Patronage capital payable

7,931,295

6,858,367

'

'

'

'

'

'

7,900,000

6,900,000

6,500,000

'

'

'

Patronage capital assigned

152,205,846

'

'

'

'

'

'

'

'

'

'

'

'

'

Patronage capital to be assigned to members

10,544,043

'

'

'

'

'

'

'

'

'

'

'

'

'

Secured debt covenant restriction

'

'

'

'

'

'

'

50.00%

'

'

'

'

30.00%

5.00%

Retirement of capital credits

1,626,828

48,079

6,761,968

1,626,828

48,079

309,188

309,188

'

'

'

'

'

'

'

Liability of capital credits

$1,470,263

$0

'

'

'

'

'

'

'

'

'

'

'

'

Other_Equities_Details

Other Equities (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
Other Equities [Line Items]	'		'
Other	$11,445,918		$11,372,355
Nonoperating Margins Prior To 1967 [Member]	'		'
Other Equities [Line Items]	'		'
Other	23,625		23,625
Donated Capital [Member]	'		'
Other Equities [Line Items]	'		'
Other	1,742,889		1,647,869
Unclaimed Capital Credit Retirement [Member]	'		'
Other Equities [Line Items]	'		'
Other	$9,679,404	[1]	$9,700,861	[1]
[1]	Represents unclaimed capital credits that have met all requirements of section 34.45.200 of Alaskabs unclaimed property law and has therefore reverted to Chugach.

Debt_Narrative_Details

Debt (Narrative) (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Nov. 17, 2010

Dec. 31, 2013

Dec. 31, 2013

4-May-12

Jun. 29, 2012

Jun. 29, 2012

Dec. 31, 2013

Dec. 31, 2012

Jan. 21, 2011

Dec. 31, 2013

Dec. 31, 2012

Jan. 21, 2011

Dec. 31, 2013

Dec. 31, 2012

Jan. 11, 2012

Dec. 31, 2013

Dec. 31, 2012

Jan. 11, 2012

Dec. 31, 2013

Dec. 31, 2012

Jan. 11, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Minimum [Member]

Maximum [Member]

2010 Amended And Extended Credit Agreement [Member]

Unsecured Credit Agreement [Member]

Unsecured Credit Agreement [Member]

Unsecured Credit Agreement [Member]

Unsecured Credit Agreement [Member]

Unsecured Credit Agreement [Member]

Unsecured Credit Agreement [Member]

Unsecured Credit Agreement [Member]

2011 Series A Bond Of 4.2% Maturing 2031 [Member]

2011 Series A Bond Of 4.2% Maturing 2031 [Member]

2011 Series A Bond Of 4.2% Maturing 2031 [Member]

2011 Series A Bond Of 4.75% Maturing 2041 [Member]

2011 Series A Bond Of 4.75% Maturing 2041 [Member]

2011 Series A Bond Of 4.75% Maturing 2041 [Member]

2012 Series A Bond Of 4.01% Maturing 2032 [Member]

2012 Series A Bond Of 4.01% Maturing 2032 [Member]

2012 Series A Bond Of 4.01% Maturing 2032 [Member]

2012 Series A Bond Of 4.41% Maturing 2042 [Member]

2012 Series A Bond Of 4.41% Maturing 2042 [Member]

2012 Series A Bond Of 4.41% Maturing 2042 [Member]

2012 Series A Bond Of 4.78% Maturing 2042 [Member]

2012 Series A Bond Of 4.78% Maturing 2042 [Member]

2012 Series A Bond Of 4.78% Maturing 2042 [Member]

Term Loan Facility [Member]

Second Amended And Restated Indenture Of Trust [Member]

CoBank Master Loan Agreement [member]

2010 Credit Agreement [Member]

Patronage Capital Distribution [Member]

Assignable Margins [Member]

Aggregate Equities And Margins To Total Liabilities And Equities And Margins [Member]

Maximum [Member]

Initial Credit Agreement [Member]

Amended Credit Agreement [Member]

Amended And Extended Credit Agreement [Member]

Amended And Extended Credit Agreement [Member]

Amended And Extended Credit Agreement [Member]

Amended And Extended Credit Agreement [Member]

item

item

item

Minimum [Member]

LIBOR [Member]

Facility Fee [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Yield margins for interest multiplier to total interest expense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.1

1.1

1.1

'

'

'

Secured debt covenant restriction

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.00%

50.00%

30.00%

Line of credit, maximum borrowing capacity

$50,000,000

'

'

'

$100,000,000

'

$300,000,000

'

'

$100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit facility, outstanding amount

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit, borrowing rate description

'The borrowing rate is calculated using the total rate per annum and may be fixed by NRUCFC.

'

'

'

'

'

'

'

'one month London Interbank Offered Rate (LIBOR) plus 107.5 basis points, along with a 17.5 basis points facility fee (based on an A- unsecured debt rating).

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit, borrowing rate

2.90%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period of time the line of credit needs to be paid down for five consecutive days

'12 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of consecutive days debt needs to be paid down to $0 during a twelve month period

'5 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit, expiration date

12-Oct-17

'

'

'

'

'

'

'

17-Nov-16

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit, initiation date

'

'

'

'

'

17-Nov-10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit, amendment date

'

'

'

'

'

'

'

'May 4, 2012

'June 29, 2012

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commercial paper, basis points on variable rate

'

'

'

'

'

'

'

'

'

'

1.08%

0.18%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commercial paper repricing term

'

'

'1 day

'270 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commercial paper

30,000,000

11,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt, issuance date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

19-Jan-11

'

'

'

'

'

'

Debt face amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$90

'

'

$185

'

'

$75

'

'

$125

'

'

$50

'

'

'

'

'

'

'

Maturity date

'

'

'

'

'

'

'

'

'

'

'

'

15-Mar-31

15-Mar-31

'

15-Mar-41

15-Mar-41

'

15-Mar-32

15-Mar-32

'

15-Mar-42

15-Mar-42

'

15-Mar-42

15-Mar-42

'

'

'

'

'

'

'

'

Bonds, interest rate

'

'

'

'

'

'

'

'

'

'

'

'

4.20%

4.20%

'

4.75%

4.75%

'

4.01%

4.01%

'

4.41%

4.41%

'

4.78%

4.78%

'

'

'

'

'

'

'

'

Frequency of payment

'

'

'

'

'

'

'

'

'

'

'

'

'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012

'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012

'

'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012

'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012

'

'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2013

'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2013

'

'interest payable semi-annually March 15 and September 15 and principal due annually between 2013 and 2020 and between 2032 and 2042

'interest payable semi-annually March 15 and September 15 and principal due annually between 2013 and 2020 and between 2032 and 2042

'

'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2023

'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2023

'

'

'

'

'

'

'

'

Average life of bond

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'10 years

'

'

'15 years 6 months

'

'

'10 years 8 months 12 days

'

'

'15 years 8 months 12 days

'

'

'20 years 8 months 12 days

'

'

'

'

'

'

'

Debt_Schedule_Of_LongTerm_Debt

Debt (Schedule Of Long-Term Debt Obligations) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
Long-term obligations, including current installments	$521,597,086	$546,090,108
Current installments of long-term obligations	24,682,812	24,493,022
Total long-term obligations, excluding current installments	496,914,274	521,597,086
CoBank 3 And 4 Variable Rate Notes Maturing In 2022 [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term obligations, including current installments	29,680,420	31,756,775
Variable interest rate	2.52%	'
Maturity date	'2022	'2022
Frequency of payment	'interest payable monthly and principal due annually beginning in 2003	'interest payable monthly and principal due annually beginning in 2003
2011 Series A Bond Of 4.2% Maturing 2031 [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term obligations, including current installments	81,000,000	85,500,000
Bonds, interest rate	4.20%	4.20%
Maturity date	15-Mar-31	15-Mar-31
Frequency of payment	'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012	'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012
2011 Series A Bond Of 4.75% Maturing 2041 [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term obligations, including current installments	172,666,666	178,833,333
Bonds, interest rate	4.75%	4.75%
Maturity date	15-Mar-41	15-Mar-41
Frequency of payment	'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012	'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2012
2012 Series A Bond Of 4.01% Maturing 2032 [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term obligations, including current installments	71,250,000	75,000,000
Bonds, interest rate	4.01%	4.01%
Maturity date	15-Mar-32	15-Mar-32
Frequency of payment	'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2013	'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2013
2012 Series A Bond Of 4.41% Maturing 2042 [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term obligations, including current installments	117,000,000	125,000,000
Bonds, interest rate	4.41%	4.41%
Maturity date	15-Mar-42	15-Mar-42
Frequency of payment	'interest payable semi-annually March 15 and September 15 and principal due annually between 2013 and 2020 and between 2032 and 2042	'interest payable semi-annually March 15 and September 15 and principal due annually between 2013 and 2020 and between 2032 and 2042
2012 Series A Bond Of 4.78% Maturing 2042 [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term obligations, including current installments	$50,000,000	$50,000,000
Bonds, interest rate	4.78%	4.78%
Maturity date	15-Mar-42	15-Mar-42
Frequency of payment	'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2023	'interest payable semi-annually March 15 and September 15 and principal due annually beginning in 2023

Debt_Schedule_Of_Maturities_Of

Debt (Schedule Of Maturities Of Long-Term Debt Obligations) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
2014	$24,682,812	'
2015	23,889,777	'
2016	24,115,980	'
2017	24,362,621	'
2018	24,631,934	'
Thereafter	399,913,962	'
Long-term obligations, including current installments	521,597,086	546,090,108
2011 Series A Bonds [Member]	'	'
Debt Instrument [Line Items]	'	'
2014	10,666,667	'
2015	10,666,667	'
2016	10,666,667	'
2017	10,666,667	'
2018	10,666,667	'
Thereafter	200,333,331	'
Long-term obligations, including current installments	253,666,666	'
CoBank Note [Member]	'	'
Debt Instrument [Line Items]	'	'
2014	2,266,145	'
2015	2,473,110	'
2016	2,699,313	'
2017	2,945,954	'
2018	3,215,267	'
Thereafter	16,080,631	'
Long-term obligations, including current installments	29,680,420	'
2012 Series A Bonds [Member]	'	'
Debt Instrument [Line Items]	'	'
2014	11,750,000	'
2015	10,750,000	'
2016	10,750,000	'
2017	10,750,000	'
2018	10,750,000	'
Thereafter	183,500,000	'
Long-term obligations, including current installments	$238,250,000	'

Debt_Schedule_Of_Weighted_Aver

Debt (Schedule Of Weighted Average Commercial Paper Balances And Weighted Average Interest Rates) (Details) (Commercial Paper [Member], USD $)

1 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Nov. 30, 2013

Oct. 31, 2013

Sep. 30, 2013

Aug. 31, 2013

Jul. 31, 2013

Jun. 30, 2013

31-May-13

Apr. 30, 2013

Mar. 31, 2013

Feb. 28, 2013

Jan. 31, 2013

Commercial Paper [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Short-term Debt [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Weighted Average Interest Rate

0.20%

0.19%

0.23%

0.21%

0.21%

0.23%

0.24%

0.24%

0.26%

0.29%

0.25%

0.27%

Average Balance

$53.10

$52.70

$49.90

$42.10

$35

$33.40

$34.30

$39.70

$40

$23.20

$0.10

$5.90

Debt_Schedule_Of_Carrying_Valu

Debt (Schedule Of Carrying Values And Estimated Fair Values Of Long-Term Debt Obligations) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
Long-term obligations, including current installments	$521,597,086	$546,090,108
Carrying Value [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term obligations, including current installments	521,597	'
Fair Value [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term obligations, including current installments	$512,435	'

Employee_Benefit_Plans_Narrati

Employee Benefit Plans (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Deferred compensation	$536,546	$570,027	$420,783
Number of days of severance paid per year of service	'14 days	'	'
Pension Plans [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Employer contributions to benefit plan	6,800,000	6,600,000	6,000,000
Union Health and Welfare Plans [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Benefit costs and employer contributions	4,100,000	4,300,000	3,700,000
Non-Union Health And Welfare Plan [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Benefit costs and employer contributions	2,900,000	2,500,000	2,400,000
Money Purchase Pension Plan [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Employer contributions to benefit plan	$147,900	$141,000	$128,700
Maximum [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Number of days of severance paid	'182 days	'	'
Number of years of service severance paid	'13 years	'	'

Employee_Benefit_Plans_Schedul

Employee Benefit Plans (Schedule Of Information For Significant Pension Plans) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Alaska Electrical Pension Plan [Member]	'		'		'
Multiemployer Plans [Line Items]	'		'		'
Employer Identification Number	'926005171	[1]	'		'
Plan Number	'001	[1]	'		'
Year-end Date	'December 31	[1]	'		'
Expiration Date of CBA's	30-Jun-17	[1]	'		'
Subject to Funding Improvement Plan	'No	[1]	'		'
Surcharge Paid	'NA	[1]	'		'
Zone Status	'Green		'Green		'Green	[1]
Required minimum contributions	'None	[1]	'None	[1]	'None	[1]
Contributions (in millions)	$3.40	[1]	$3.60	[1]	$3	[1]
Contributions > 5% of total plan contributions	'Yes	[1]	'Yes	[1]	'Yes	[1]
NRECA Retirement Security Plan [Member]	'		'		'
Multiemployer Plans [Line Items]	'		'		'
Employer Identification Number	'530116145	[1]	'		'
Plan Number	'333	[1]	'		'
Year-end Date	'December 31	[1],[2]	'		'
Subject to Funding Improvement Plan	'No	[1],[3]	'		'
Surcharge Paid	'NA	[1],[3]	'		'
Zone Status	'NA	[4]	'NA	[4]	'NA	[4]
Required minimum contributions	'NA	[1]	'NA	[1]	'NA	[1]
Contributions (in millions)	$3.40	[1]	$3	[1]	$3	[1]
Contributions > 5% of total plan contributions	'No	[1]	'No	[1]	'No	[1]
[1]	The Alaska Electrical Pension Plan is publicly available. The NRECA Retirement Security Plan is available on Chugachbs website at www.chugachelectric.com.
[2]	The CEO is the only non-union employee subject to an employment agreement, which is effective through July 17, 2016.
[3]	The provisions of the PPA do not apply to the RS Plan, therefore, funding improvement plans and surcharges are not applicable. Future contribution requirements are determined each year as part of the actuarial valuation of the RS Plan and may change as a result of plan experience.
[4]	A bzone statusb determination is not required, and therefore not determined under the Pension Protection Act (PPA) of 2006.

Bradley_Lake_Hydroelectric_Pro2

Bradley Lake Hydroelectric Project (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Unrecorded Unconditional Purchase Obligation [Line Items]	'	'	'
Bonds payable	$469,499,999	$491,916,666	'
Purchased power	27,836,680	22,104,687	25,861,814
Bradley Lake Hydroelectric Project [Member]	'	'	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'	'	'
Percentage share of power purchased	30.40%	'	'
Amount of committed purchased power	27.4	'	'
Portion of outstanding debt	26,600,000	'	'
Threshold percentage for increasing plant costs	25.00%	'	'
Purchased power	4,882,163	4,223,784	4,643,641
Revenue Bonds [Member] | Alaska Energy Authority [Member] | Bradley Lake Hydroelectric Project [Member]	'	'	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'	'	'
Bonds, face value	166,000,000	'	'
Forecast [Member] | Bradley Lake Hydroelectric Project [Member]	'	'	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'	'	'
Estimated entitled additional energy output percentage	30.40%	'	'
Purchased power	$5,200,000	'	'
Maximum [Member] | Forecast [Member] | Bradley Lake Hydroelectric Project [Member]	'	'	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'	'	'
Estimated increase in annual energy output	40,000	'	'

Bradley_Lake_Hydroelectric_Pro3

Bradley Lake Hydroelectric Project (Bradley Lake Project Financials) (Details) (USD $)

3 Months Ended

12 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 30, 2012

Jun. 30, 2012

Bradley Lake Hydroelectric Project [Member]

Bradley Lake Hydroelectric Project [Member]

Alaska Energy Authority [Member]

Alaska Energy Authority [Member]

Proportionate Share [Member]

Unrecorded Unconditional Purchase Obligation [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Electric Plant in service

$1,135,356,956

'

'

'

$891,781,509

'

'

'

$1,135,356,956

$891,781,509

'

$177,968,000

$54,102,000

Long term debt

521,597,086

'

'

'

546,090,108

'

'

'

521,597,086

546,090,108

'

80,117,000

24,356,000

Interest expense

$6,014,808

$6,016,792

$6,058,246

$5,291,626

$3,492,044

$3,495,865

$3,542,676

$3,872,346

$23,381,472

$14,402,931

$16,746,977

$4,618,000

$1,404,000

Eklutna_Hydroelectric_Project_

Eklutna Hydroelectric Project (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Jointly Owned Utility Plant Interests [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Net utility plant	$699,150,797	'	'	'	$705,975,228	'	'	'	$699,150,797	$705,975,228	'
Net utility plant	699,150,797	'	'	'	705,975,228	'	'	'	699,150,797	705,975,228	'
Less accumulated depreciation	-464,880,322	'	'	'	-449,266,075	'	'	'	-464,880,322	-449,266,075	'
Accumulated depreciation	464,880,322	'	'	'	449,266,075	'	'	'	464,880,322	449,266,075	'
Total operating expenses	73,756,307	67,061,684	70,076,488	67,844,018	68,250,215	60,200,529	55,725,151	64,019,060	278,738,497	248,194,955	262,341,866
Eklutna Hydroelectric Project [Member]	'	'	'	'	'	'	'	'	'	'	'
Jointly Owned Utility Plant Interests [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Percentage ownership	30.00%	'	'	'	'	'	'	'	30.00%	'	'
Net utility plant	4,562,310	'	'	'	4,725,470	'	'	'	4,562,310	4,725,470	'
Net utility plant	4,562,310	'	'	'	4,725,470	'	'	'	4,562,310	4,725,470	'
Less accumulated depreciation	-1,854,083	'	'	'	-1,671,335	'	'	'	-1,854,083	-1,671,335	'
Accumulated depreciation	1,854,083	'	'	'	1,671,335	'	'	'	1,854,083	1,671,335	'
Total operating expenses	'	'	'	'	'	'	'	'	$730,122	$682,757	$662,035
Matanuska Electric Association, Inc. [Member] | Eklutna Hydroelectric Project [Member]	'	'	'	'	'	'	'	'	'	'	'
Jointly Owned Utility Plant Interests [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Percentage ownership	17.00%	'	'	'	'	'	'	'	17.00%	'	'
Municipal Light & Power [Member] | Eklutna Hydroelectric Project [Member]	'	'	'	'	'	'	'	'	'	'	'
Jointly Owned Utility Plant Interests [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Percentage ownership	53.00%	'	'	'	'	'	'	'	53.00%	'	'

Commitments_And_Contingencies_1

Commitments And Contingencies (Narrative) (Details) (USD $)

3 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Mar. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

item

Beluga Power Plant [Member]

Beluga Power Plant [Member]

Beluga Power Plant [Member]

Cooper Lake Hydroelectric Project [Member]

Southcentral Power Project [Member]

Homer Electric Association, Inc. And Matanuska Electric Association, Inc. [Member]

Homer Electric Association, Inc. And Matanuska Electric Association, Inc. [Member]

Homer Electric Association, Inc. And Matanuska Electric Association, Inc. [Member]

Homer Electric Association, Inc. [Member]

Homer Electric Association, Inc. [Member]

Homer Electric Association, Inc. [Member]

Homer Electric Association, Inc. [Member]

ConocoPhillips (COP) [Member]

Marathon Alaska Production, LLC [Member]

Hilcorp Alaska - Cook Inlet [Member]

Cook Inlet Energy, LLC [Member]

Cook Inlet Energy, LLC [Member]

MMcf

MMcf

Commitments And Contingencies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of employees belonging to unions

'

'

'

'

'

'

'

'

70.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of collective bargaining with the IBEW

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating revenues

$81,068,132

$71,715,353

$74,776,425

$77,748,517

$74,483,455

$62,675,511

$58,631,729

$71,180,773

$305,308,427

$266,971,468

$283,618,369

'

'

'

'

'

$103,100,000

$100,600,000

$104,000,000

'

'

'

'

'

'

'

'

'

Customer percentage of operating revenue

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

34.00%

39.00%

37.00%

'

'

'

'

'

'

'

'

'

Commencement date of long term contract for transportation of gas supply

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1-Oct-12

'

'

Commencement date of long term contract for purchase of gas supply

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21-Aug-09

1-Apr-11

'

'

1-Apr-14

Expiration date of long term contract for tranportation of gas supply

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

30-Sep-13

'

'

Expiration date of long term contract for purchase of gas supply

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

31-Dec-16

31-Mar-18

'

'

31-Mar-18

Estimated amount of gas under contract

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

60,000

40,000

'

'

'

Percentage of fuel supply needs filled by contracts

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of power generated from gas

'

'

'

'

'

'

'

'

87.00%

89.00%

92.00%

47.00%

83.00%

79.00%

'

31.00%

'

'

'

'

'

'

'

'

'

'

'

'

Number of years to return patronage capital after expiration of power agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

Patronage capital

162,749,889

'

'

'

153,832,674

'

'

'

162,749,889

153,832,674

'

'

'

'

'

'

'

'

'

'

'

'

6,500,000

'

'

'

'

'

Patronage capital payable

7,931,295

'

'

'

6,858,367

'

'

'

7,931,295

6,858,367

'

'

'

'

'

'

'

'

'

7,900,000

6,900,000

6,500,000

'

'

'

'

'

'

Regulatory initial cost charge per KWH

'

'

'

'

'

'

'

'

0.000626

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory current cost charge per KWH

'

'

'

'

'

'

'

'

0.000578

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of retail bill collected to move existing overhead lines underground

'

'

'

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of three year average of gross retail revenue to be spent on underground lines

'

'

'

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Average of gross revenue to determine expenditure for underground lines

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liability for moving overhead lines underground

2,898,558

'

'

'

3,786,031

'

'

'

2,898,558

3,786,031

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Duration of license agreement with FERC

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'50 years

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated cost to complete project at time of relicense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated project costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Grants received from state

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Grants authorized from state

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,760,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Contract time period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'April 1, 2014, and terminating on March 31, 2018

'

Commitments_And_Contingencies_2

Commitments And Contingencies (Schedule Of Costs Of Fuel Purchased And Transported As A Percentage Of Total Fuel Costs) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Marathon Oil Company [Member]	'	'	'
Other Commitments [Line Items]	'	'	'
Cost of fuel purchased and transported as a percentage of total fuel costs	4.50%	72.00%	44.90%
Chevron Unocal Hilcorp [Member]	'	'	'
Other Commitments [Line Items]	'	'	'
Cost of fuel purchased and transported as a percentage of total fuel costs	46.40%	1.30%	16.10%
Municipal Light & Power [Member]	'	'	'
Other Commitments [Line Items]	'	'	'
Cost of fuel purchased and transported as a percentage of total fuel costs	0.00%	0.00%	3.60%
ConocoPhillips (COP) [Member]	'	'	'
Other Commitments [Line Items]	'	'	'
Cost of fuel purchased and transported as a percentage of total fuel costs	42.80%	24.20%	31.90%
ENSTAR Natural Gas Company [Member]	'	'	'
Other Commitments [Line Items]	'	'	'
Cost of fuel purchased and transported as a percentage of total fuel costs	2.10%	2.20%	1.30%
Hilcorp Alaska, LLC [Member]	'	'	'
Other Commitments [Line Items]	'	'	'
Cost of fuel purchased and transported as a percentage of total fuel costs	3.80%	0.00%	0.00%
Miscellaneous [Member]	'	'	'
Other Commitments [Line Items]	'	'	'
Cost of fuel purchased and transported as a percentage of total fuel costs	0.40%	0.30%	2.20%

Gain_On_Sale_Of_Asset_Details

Gain On Sale Of Asset (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Gain On Sale of Asset [Abstract]	'	'	'
Gain of sale of asset	$6,436,992	$0	$0

Quarterly_Results_Of_Operation2

Quarterly Results Of Operations (Unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statements Of Operations [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Operating revenues	$81,068,132	$71,715,353	$74,776,425	$77,748,517	$74,483,455	$62,675,511	$58,631,729	$71,180,773	$305,308,427	$266,971,468	$283,618,369
Operating expenses	73,756,307	67,061,684	70,076,488	67,844,018	68,250,215	60,200,529	55,725,151	64,019,060	278,738,497	248,194,955	262,341,866
Net interest	6,014,808	6,016,792	6,058,246	5,291,626	3,492,044	3,495,865	3,542,676	3,872,346	23,381,472	14,402,931	16,746,977
Net operating margins	1,297,017	-1,363,123	-1,358,309	4,612,873	2,741,196	-1,020,883	-636,098	3,289,367	3,188,458	4,373,582	4,529,526
Nonoperating margins	6,918,314	226,803	-18,235	228,703	632,775	261,487	123,962	133,701	7,355,585	1,151,925	1,043,736
Assignable margins	$8,215,331	($1,136,320)	($1,376,544)	$4,841,576	$3,373,971	($759,396)	($512,136)	$3,423,068	$10,544,043	$5,525,507	$5,573,262