Chugach Electric Association 10-Q 12 Aug 16 2016 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information	6 Months Ended
	Jun. 30, 2016shares
Document And Entity Information [Abstract]
Entity Registrant Name	CHUGACH ELECTRIC ASSOCIATION INC
Entity Filer Category	Non-accelerated Filer
Entity Central Index Key	878,004
Amendment Flag	false
Document Type	10-Q
Document Fiscal Period Focus	Q2
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2,016
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding	0

Balance Sheets

Balance Sheets - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Utility Plant:
Electric plant in service	$ 1,179,383,291	$ 1,128,474,292
Construction work in progress	21,291,288	15,601,374
Total utility plant	1,200,674,579	1,144,075,666
Less accumulated depreciation	(483,305,605)	(469,199,226)
Net utility plant	717,368,974	674,876,440
Other property and investments, at cost:
Nonutility property	76,889	76,889
Investments in associated organizations	9,316,839	9,635,519
Special funds	830,234	763,913
Restricted cash equivalents	1,796,365	1,705,760
Total other property and investments	12,020,327	12,182,081
Current assets:
Cash and cash equivalents	14,716,696	15,626,919
Special deposits	74,416	74,416
Restricted cash equivalents	1,052,960	1,143,467
Accounts receivable, net	25,133,242	28,232,930
Materials and supplies	27,414,881	27,611,184
Fuel stock	7,378,360	7,063,541
Prepayments	2,751,222	1,466,301
Other current assets	155,851	225,079
Total current assets	78,677,628	81,443,837
Deferred charges, net	18,021,094	16,811,756
Total assets	826,088,023	785,314,114
Equities and margins:
Memberships	1,675,014	1,661,744
Patronage capital	167,964,097	167,447,781
Other	12,586,665	12,527,856
Total equities and margins	182,225,776	181,637,381
Long-term obligations, excluding current installments:
Bonds payable	405,249,998	426,666,665
Notes payable	41,952,000	22,241,852
Less unamortized debt issuance costs	(2,801,913)	(2,680,897)
Total long-term obligations	444,400,085	446,227,620
Current liabilities:
Current installments of long-term obligations	47,306,519	24,115,980
Commercial paper	34,000,000	20,000,000
Accounts payable	10,429,741	9,701,088
Consumer deposits	4,895,477	5,000,684
Fuel cost over-recovery	3,971,610	5,135,745
Accrued interest	5,640,097	5,915,580
Salaries, wages and benefits	7,667,014	7,259,806
Fuel	5,321,216	4,942,310
Other current liabilities	8,045,329	8,076,903
Total current liabilities	127,277,003	90,148,096
Other non-current liabilities:
Deferred compensation	830,234	763,913
Other liabilities, non-current	1,757,959	1,555,329
Deferred liabilities	1,317,135	1,802,389
Patronage capital payable	11,108,071	11,108,071
Cost of removal obligation	57,171,760	52,071,315
Total other non-current liabilities	72,185,159	67,301,017
Total liabilities, equities and margins	$ 826,088,023	$ 785,314,114

Statements Of Operations

Statements Of Operations - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Statements Of Operations [Abstract]
Operating revenues	$ 44,622,517	$ 47,697,820	$ 94,872,652	$ 122,670,937
Operating expenses:
Fuel	11,946,563	13,185,841	25,835,500	43,017,838
Production	4,044,758	4,089,615	7,893,027	8,657,297
Purchased power	4,241,600	4,729,596	8,190,828	11,336,198
Transmission	1,338,879	1,489,944	2,715,746	3,053,626
Distribution	3,414,636	3,591,277	6,760,579	6,841,841
Consumer accounts	1,562,887	1,586,015	3,195,100	3,127,606
Administrative, general and other	6,228,353	6,049,377	12,058,320	12,144,723
Depreciation and amortization	8,695,032	8,768,893	17,182,680	18,762,705
Total operating expenses	41,472,708	43,490,558	83,831,780	106,941,834
Interest expense:
Long-term debt and other	5,352,456	5,503,640	10,836,220	11,212,552
Charged to construction	(105,051)	(122,473)	(203,604)	(242,012)
Interest expense, net	5,247,405	5,381,167	10,632,616	10,970,540
Net operating margins	(2,097,596)	(1,173,905)	408,256	4,758,563
Nonoperating margins:
Interest income	83,221	78,740	164,337	146,837
Allowance for funds used during construction	43,449	46,070	84,211	91,035
Capital credits, patronage dividends and other	1,200	1,200	2,400	2,400
Total nonoperating margins	127,870	126,010	250,948	240,272
Assignable margins	$ (1,969,726)	$ (1,047,895)	$ 659,204	$ 4,998,835

Statements Of Cash Flows

Statements Of Cash Flows - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Cash flows from operating activities:
Assignable margins	$ 659,204	$ 4,998,835
Adjustments to reconcile assignable margins to net cash provided by operating activities:
Depreciation and amortization	17,182,680	18,762,705
Amortization and depreciation cleared to operating expenses	2,584,237	2,243,869
Allowance for funds used during construction	(84,211)	(91,035)
Write off of inventory, deferred charges and projects	460,364	160,325
Other	(104,275)	2,280
(Increase) decrease in assets:
Accounts receivable, net	2,964,271	12,013,381
Materials and supplies	30,011	(2,349,758)
Fuel stock	(314,819)	5,595,105
Prepayments	(1,284,921)	(624,366)
Other assets	69,228	80,404
Deferred charges	(2,197,850)	(61,793)
Increase (decrease) in liabilities:
Accounts payable	1,386,823	(1,689,849)
Consumer deposits	(105,207)	(107,559)
Fuel cost over-recovery	(1,164,135)	6,572,139
Accrued interest	(275,483)	(279,800)
Salaries, wages and benefits	407,208	648,747
Fuel	378,906	(6,029,560)
Other current liabilities	88,223	(639,723)
Deferred liabilities	6,238	(68,741)
Net cash provided by operating activities	20,686,492	39,135,606
Cash flows from investing activities:
Return of capital from investment in associated organizations	318,680	352,420
Investment in restricted cash equivalents	(98)	0
Investment in Beluga River Unit	(44,183,293)	0
Proceeds from capital grants	377,796	1,097,228
Extension and replacement of plant	(15,241,226)	(10,320,118)
Net cash used in investing activities	(58,728,141)	(8,870,470)
Cash flows from financing activities:
Payments for debt issue costs	(235,504)	0
Net increase (decrease) in short-term obligations	14,000,000	(11,000,000)
Proceeds from long-term obligations	45,600,000	0
Repayments of long-term obligations	(24,115,980)	(23,889,777)
Memberships and donations received	72,079	661
Retirement of patronage capital and estate payments	(142,888)	(85,569)
Net receipts on consumer advances for construction	1,953,719	1,970,102
Net cash provided by (used in) financing activities	37,131,426	(33,004,583)
Net change in cash and cash equivalents	(910,223)	(2,739,447)
Cash and cash equivalents at beginning of period	15,626,919	16,364,962
Cash and cash equivalents at end of period	14,716,696	13,625,515
Supplemental disclosure of non-cash investing and financing activities:
Cost of removal obligation	5,100,445	(74,064)
Extension and replacement of plant included in accounts payable	1,782,961	2,930,051
Supplemental disclosure of cash flow information - interest expense paid, net of amounts capitalized	$ 10,150,305	$ 10,635,938

Presentation Of Financial Infor

Presentation Of Financial Information	6 Months Ended
	Jun. 30, 2016
Presentation Of Financial Information [Abstract]
Presentation Of Financial Information	1. PRESENTATION OF FINANCIAL INFORMATION  The accompanying unaudited interim financial statements include the accounts of Chugach and have been prepared in accordance with generally accepted accounting principles for interim financial information . Accordingly, they do not include all of the information and footnotes required by United States of America generally accepted accounting principles (U.S. GAAP) for complete financial statements . They should be read in conjunction with Chugach’s audited financial statements for the year ended December 31, 201 5 , filed as part of Chugach’s annual report on Form 10-K . In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included . The results of operations for interim periods are not necessarily indicative of the results that may be expected for an entire year or any other period. 

Description Of Business

Description Of Business	6 Months Ended
	Jun. 30, 2016
Description Of Business [Abstract]
Description Of Business	2. DESCRIPTION OF BUSINESS  Chugach is the largest electric utility in Alaska. Chugach is engaged in the generation, transmission and distribution of electricity in the Anchorage and upper Kenai Peninsula areas. Chugach is on an interconnected regional electrical system referred to as the Alaska 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’s retail and wholesale members are the consumers of the electricity sold. Chugach supplies much of the power requirements of the City of Seward (Seward) , as a wholesale customer . Chugach also served Matanuska Electric Association, Inc. (MEA) , as a wholesale customer, through April 30, 2015 , and Golden Valley Electric Association, Inc. (GVEA), as an economy , non-firm , energy customer, through March 31, 2015 . Periodically, Chugach sells available generation , in excess of its own needs , to MEA, GVEA and Anchorage Municipal Light & Power (ML&P).  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).  Chugach has three Collective Bargaining Agreements (CBA’s) with the International Brotherhood of Electrical Workers (IBEW), representing approximately 70% of its workforce. Chugach also has an agreement with the Hotel Employees and Restaurant Employees (HERE). All three IBEW CBA’s have been renewed th rough June 30, 2017 . The three CBA’s provide for wage increases in all years and include health and welfare premium cost sharing provisions. The HERE contract was renewed through June 30, 2016 . This contract will remain in effect until negotiations conclude, which are currently scheduled for the fourth quarter of 2016 .

Significant Accounting Policies

Significant Accounting Policies	6 Months Ended
	Jun. 30, 2016
Significant Accounting Policies [Abstract]
Significant Accounting Policies	3. SIGNIFICANT ACCOUNTING POLICIES  a. Management Estimates  In preparing the financial statements in conformity with U.S. 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 liability, deferred charges and credits, unbilled revenue, estimated useful life of utility plant, cost of removal and asset retirement obligation (ARO), purchase price allocation for Beluga River Unit (BRU), and remaining proved BRU reserves. Actual results could differ from those estimates.  b. Full Cost Method  Pursuant to Accounting Standards Codification (ASC) 932-360-25, “Extractive Activities-Oil and Gas – Property, Plant and Equipment – Recognition”, Chugach has elected the Full C ost method, rather than the Successful Efforts method, to account for exploration and development costs of gas reserves. This is the first time Chugach has invested in oil or gas activities, so there is no prior policy of using the Successful Efforts method.  c. Depreciation, Depletion and Amortization (DD&A)  Chugach records DD&A expense on the BRU assets based on units of production using the following formula: ten percent of the total production from the BRU as provided by the operator divided by ten percent of the estimated remaining proved reserves (in Mcf) in the field multiplied by Chugach’s total assets in the BRU.  d. Asset Retirement Obligation (ARO)  Chugach calculated and recorded an Asset Retirement Obligation associated with the BRU. Chugach uses its BRU financing rate as its credit adjusted risk free rate and the expected cash flow approach to calculate the fair value of the ARO liability. The ARO asset is depreciated using the DD&A formula outlined above. The ARO liability is accreted using the interest method of allocation.  e. 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. Chugach’s regulated rates are established to recover all of the specific costs of providing electric service. In each rate filing, rates are set at levels to recover all of the specific allowable costs and those rates are then collected from retail and wholesale customers. The regulatory assets or liabilities are then reduced as the cost or credit is reflected in earnings and rates.  f. 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 six month periods ended June 30, 2016 and 2015 was in compliance with that provision.  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.  g. Restricted Cash Equivalents  Restricted cash equivalents include funds on deposit for future workers’ compensation claims, which amounted to $2.8 million at June 30, 2016, and December 31, 2015.  h. Accounts Receivable  Included in accounts receivable are invoiced amounts to ML&P for their proportionate share of current Southcentral Power Project (SPP) costs, which amounted to $1.1 million at June 30, 2016, and December 31, 2015. 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 $0.2 million at December 31, 2015. At June 30, 2016, accounts receivable also includes $0.3 million from BRU operations primarily associated with gas sales to ENSTAR.  i. Fuel Stock  Fuel Stock is the weighted average cost of fuel injected into the Cook Inlet Natural Gas Storage Alaska (CINGSA). Chugach’s fuel balance in storage amounted to $7.4 million and $7.1 million at June 30, 2016, and December 31, 2015, respectively.  h. Corrections  For the period ended June 30, 2016, Chugach recorded the following correction for the period ended June 30, 2015:  A correction representing the cash received from customers for the undergrounding ordinance, included in net receipts on consumer advances for construction, previously reported as other current liabilities. The impact of this correction was a decrease in cash provided by operating activities and cash used in financing activities of $1.7 million for the six months ended June 30, 2015. 

Regulatory Matters

Regulatory Matters	6 Months Ended
	Jun. 30, 2016
Regulatory Matters [Abstract]
Regulatory Matters	4. REGULATORY MATTERS  Amended Eklutna Generation Station 2015 Dispatch Services Agreement  On February 13, 2015, Chugach submitted the Amended Eklutna Generation Station 2015 Dispatch Services Agreement (Dispatch Services Agreement) to the RCA for dispatch services to be provided by Chugach to MEA for a one -year period. Under the Dispatch Services Agreement, Chugach provides electric and natural gas dispatch services for MEA’s Eklutna Generation Station (EGS), electric dispatch services for the Bradley Lake Hydroelectric Project (Bradley Lake), and electric dispatch coordination services for the Eklutna Hydroelectric Project (Eklutna Hydro) beginning with EGS’ s full commercial operation.  On March 23, 2015, the RCA approved the Dispatch Agreement, conditioned on the requirements that 1) MEA and Chugach notify the RCA at least one month prior to forming separate Load Balancing Authorities and include in any such notification details on the tie points and any written agreements contemplated by the utilities; and, 2) Chugach file an update to its tariff to reflect any extension of the Dispatch Services Agreement one week from the receipt of such a request from MEA. The Dispatch Services Agreement was in effect through March 31, 2016 .  In December 2015, MEA notified Chugach that it would not be extending the Dispatch Services Agreement for the dispatch of electric service. Subsequently, Chugach and MEA entered into an agreement entitled, “Gas Dispatch Agreement” in which Chugach provides gas scheduling and dispatch services to MEA. The term of the agreement is April 1, 2016 , through March 31, 2017 . On April 18, 2016, Chugach requested RCA approval of the special contract. The RCA issued a letter order on June 8, 2016, approving the filing . This agreement was extended through March 31, 2018 , in a letter agreement dated July 29, 2016, with a provision to extend the agreement through March 31, 2019 , to be exercised on or before August 1, 2017. Extension of Contract Term: 2006 Agreement for the Sale and Purchase Agreement between Chugach and the City of Seward  On June 2, 2016, Chugach submitted an updated listing of its special contracts to reflect the extension of the expiration date of the “2006 Agreement for the Sale and Purchase of Electric Power and Energy between Chugach Electric Association, Inc. and the City of Seward” (2006 Agreement) from December 31, 2016 , to December 31, 2021 .  The 2006 Agreement contains an evergreen clause providing for an automatic five -year extension unless written notice is provided at least one year prior to the expiration date. Neither Chugach nor Seward provided written notice to terminate as both utilities desired to extend the term of the agreement. On July 18, 2016, the RCA approved the filing.  June 2014 Test Year General Rate Case  Chugach’s June 2014 Test Year General Rate Case was submitted to the RCA on February 13, 2015. Chugach requested a system base rate increase of approximately $21.3 million, or 20% , on total base rate revenues for rates effective in April 2015. The filing also included updates to firm and non-firm transmission wheeling rates and attendant ancillary services in support of third-party transactions on the Chugach transmission system. The primary driver of the rate changes was the reduction and shift in fixed-cost responsibility resulting from the expiration of the Interim Power Sales Agreement between Chugach and MEA on April 30, 2015 .  Chugach submitted proposed adjustments to its fuel and purchased power rates under a separate tariff advice letter to become effective at the same time which allow ed interim base rate increases to be synchronized with reductions in fuel costs resulting from system heat rate improvements and a greater share of hydroelectric generation used to meet the load requirements of the remaining customers on the system. In combination with Chugach’s fuel and purchased power rate adjustment filing for rates effective in April 2015, the effective increase to retail customer bills was approximately between two and five percent.  The RCA issued Order U-15-081(1) on April 30, 2015, suspending the filing and granting Chugach’s request for interim and refundable rate increases effective May 1, 2015. A scheduling conference was held on May 27, 2015. On June 4, 2015, the RCA issued Order U-15-081(2), granting approval for intervention by Homer Electric Association (HEA), MEA and GVEA. The RCA ha d indicated that a final order in the case would be issued by May 8, 2016. Intervenor responsive testimony was filed by the Attorney General (AG) and MEA on October 28, 2015. The AG’s testimony focused on revenue requirement matters and MEA’s testimony focused on transmission cost allocation issues. Chugach’s responsive testimony was filed on December 15, 2015.  In January 2016, Chugach and the Attorney General (AG) for the State of Alaska entered into settlement discussions to resolve revenue requirement matters in the case, which resulted in settlement of all outstanding matters related to the determination of Chugach’s system revenue requirement for both the interim and permanent rate periods. As a result, Chugach agreed to reduce its revenue requirement by 0.5% . In addition, the stipulation provide d for a permanent increase in Chugach’s system Times Interest Earned Ratio (TIER) from 1.30 to 1.35 , which represents an approximate margin increase of $1.0 million per year. The stipulation was filed wi th the RCA on January 21, 2016.  The adjudicatory hearing was held from January 25 through January 28, 2016, to address transmission-related matters identified by MEA. Because of the settlement, no revenue requirement matters were addressed during the hearing.  On May 2, 2016, the RCA issued Order U-15-081(8) accepting the stipulation between Chugach and the AG. On May 20, 2016, Chugach submitted updated revenue requirement, cost of service and tariffs reflecting the results of the stipulation, with proposed final rates effective July 5, 2016 . On June 17, 2016, the RCA issued Order U-15-081(10) approving final permanent rates effective for Chugach retail customers and the City of Seward (Seward). Refunds totaling $0.75 million are expected to be issued to Chugach retail customers in August 2016. The refund applies to purchases from May 2015 through July 2016. Chugach issued a refund to Seward totaling approximately $28,000 on July 8, 2016.  On June 27, 2016, the RCA issued Order U-15-08(11) resolving the outstanding issues related to transmission and ancillary services. The RCA ruled in Chugach’s favor, affirming continued use of a postage stamp rate methodology for wheeling transactions on the Chugach system and denied MEA’s request for a separate rate for wheeling transactions that MEA claimed it only used a small portion of Chugach’s transmission system. The order was consistent with previous orders on transmission and ancillary services that were issued by the RCA in Chugach’s 2012 and 2013 General Rate Case filings. On July 15, 2016, Chugach submitted updated tariff sheets and supporting exhibits for the calculation of transmission and ancillary service rates.  Simplified Rate Filing  On June 30, 2016, the Chugach Board of Directors voted to re-enter the Simplified Rate Filing (SRF) process for adjustments to base demand and energy rates. SRF is an expedited base rate adjustment process available to electric cooperatives in the State of Alaska. On July 1, 2016, Chugach requested approval to implement the SRF process for energy and demand rate changes, and requested approval for a 4.2% system demand and energy rate increase, or approximately $4.8 million on an annual basis. On a total retail customer bill basis, which includes fuel and purchased power costs, the impact is approximately 2.5% . Chugach requested the proposed rate increase become effective August 15, 2016 . Under SRF, the RCA is required to respond within 45 days or approximately August 15, 2016. Chugach plans to adjust rates through the SRF process on a quarterly basis going forward.  C ook I nlet N atural G as Storage A laska (CINGSA): Found Gas  On January 30, 2015, CINGSA submitted a filing to the RCA providing notice that it had found 14.5 Bcf of gas as a result of directional drilling in the storage facility and now proposes to establish guidelines for commercial sales of at least 2 Bcf of this gas. Chugach submitted comments to the RCA regarding CINGSA’s proposed treatment of found gas. Chugach does not believe CINGSA’s proposal to retain revenues for the sale of found gas should be permitted in recognition of the risk-sharing agreements made by CINGSA and its storage customers that resulted in the development of the CINGSA storage facility.  The RCA issued an order in March 2015 suspending the filing for further investigation. CINGSA filed direct testimony in the case on April 13, 2015. Chugach and other intervenors in the case submitted responsive testimony on June 5, 2015. CINGSA submitted its reply testimony on June 29, 2015. The evidentiary hearing was held in September 2015.  The RCA issued a final order in the case on December 4, 2015, ruling significantly in favor of the intervenors in the case. The RCA granted approval for CINGSA to sell 2 Bcf with 87% of the proceeds allocated to CINGSA’s Firm Storage Service (FSS) customers and 13% to CINGSA. The RCA also required CINGSA to file a reservoir engineering study by June 30, 2016, and required CINGSA to file notice of all gas sales within 30 days of any sales, including the transaction price, purchaser, quantities, and the terms and conditions of the sale. The RCA also required that all proceeds to the FSS customers be treated as a reduction in fuel costs that are paid by CINGSA’s customers. On June 30, 2016, CINGSA filed a reservoir engineering study with the RCA by Order U-15-016(14).  On January 4, 2016, CINGSA filed an appeal in Superior Court to Order U-15-016(14), stating the RCA violated CINGSA’s right to due process of law, errored, and/or acted unreasonably, unfairly, arbitrarily, capriciously, or contrary to applicable law. CINGSA believes additional proceeds resulting from the sale of found native gas should remain with CINGSA. Chugach filed an entry of appearance in the case on January 14, 2016. CINGSA filed its brief on June 6, 2016. Chugach expects to file its reply brief during the third quarter of 2016.  Belu ga River Unit  In July 2015, ConocoPhillips Alaska, Inc. (COP) announced the marketing for sale of its North Cook Inlet Unit; its interest in the Beluga River Unit (BRU); and its interest in 5,700 acres of exploration prospects in the Cook Inlet region. In October 2015, Chugach submitted a joint bid with the Municipality of Anchorage d/b/a Municipal Light & Power (ML&P) for acquisition of COP’s working interest in the BRU.  As discussed in “ Note 9 –Beluga River Unit ,” Chugach entered into an agreement entitled, “Purchase and Sale Agreement between ConocoPhillips Alaska, Inc. and Municipality of Anchorage d/b/a Municipal Light & Power and Chugach Electric Association, Inc.” (Purchase and Sale Agreement) on February 4, 2016 . The Purchase and Sale Agreement transfers COP’s interest in the BRU to Chugach and ML&P. The acquisition and attendant recovery of costs in electric rates was subject to RCA approval.  On March 11, 2016, Chugach and ML&P submitted a joint request to the RCA for approval of the acquisition of ConocoPhillips Alaska, Inc.’s interest in the BRU and the attendant recovery of the acquisition costs in electric rates. Chugach and ML&P requested expedited consideration, asking the RCA to issue a bench ruling by April 21, 2016. The request for expedited consideration was made to provide additional certainty regarding Chugach’s eligibility for a State of Alaska production tax credit.  The RCA opened docket U-15-081 and established an expedited procedural schedule for the case. The RCA held a hearing from April 18 through April 20, 2016, and issued a bench ruling on April 20, 2016, approving the joint request for approval of the Purchase and Sale Agreement. A written order affirming the bench ruling was issued on April 21, 2016.  Separate filings detailing the specific rate recovery process were filed in the second quarter of 2016. The RCA approved the initial gas transfer price of $5.88 per Mcf. Under the recovery structure proposed by Chugach, costs associated with the BRU, including acquisition and on-going operations, maintenance and capital investment, will be recovered on a dollar-for-dollar basis through Chugach’s quarterly fuel adjustment process. Chugach recovers its fuel and purchased power costs as a direct pass-through from its retail and wholesale customers with minimal lag between cost incurrence and recovery. A decision is expected in the third quarter of 2016.  On June 29, 2016, Chugach filed a petition with the RCA for approval to create a regulatory asset for the deferral of expenses (financial/economic, engineering and legal services) associated with Chugach’s acquisition of the BRU. Chugach also requested approval to recover the deferred costs in the gas transfer price. A decision is expected by year-end. 

Debt

Debt	6 Months Ended
	Jun. 30, 2016
Debt [Abstract]
Debt	5. DEBT  Lines of Credit  Chugach maintains a $50.0 million line of credit with National Rural Utilities Cooperative Finance Corporation (NRUCFC). Chugach did not utilize this line of credit in the six months ended June 30 , 2016. In addition, Chugach did not utilize this line of credit during 2015 and had no outstanding balance at December 31, 2015. The borrowing rate is calculated using the total rate per annum and may be fixed by NRUCFC. The borrowing rate was 2.50 and 2.90 percent at June 30 , 2016, and December 31, 2015. 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. The NRUCFC line of credit expires October 12, 2017 . This line of credit is immediately available for unconditional borrowing. Commercial Paper  Chugach maintain ed a $100.0 million Amended Unsecured Credit Agreement, which wa s used to back Chugach’s commercial paper program. The pricing include d 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 was due to expire on November 17, 2016 . The participating banks include d NRUCFC, KeyBank National Association, Bank of America, N.A., Bank of Montreal, CoBank and Chang Hwa Commercial Bank, Ltd., Los Angeles Branch.  On June 13, 2016 , Chugach entered into a $150.0 million senior unsecured credit facility, the Credit Agreement, which i s used to back Chugach’s commercial paper program. The pricing include s an all-in drawn spread of one month LIBOR plus 90.0 basis points, along with a 10.0 basis points facility fee (based on an A/A2/A unsecured debt rating) . The new Credit Agreement will expire on June 13, 2021 . The participating banks include NRUCFC, KeyBank National Association, Bank of America, N.A., and CoBank , ACB . The commercial paper c an be repriced between one day and 270 days.  Chugach expect s to continue issuing commercial paper in 2016, as needed. Chugach had $34.0 million and $20.0 million of commercial paper outstanding at June 30 , 2016, and December 31, 2015, respectively.  The following table provides information regarding average commercial paper balances outstanding for the quarters ended June 30 , 2016, and 2015 (dollars in millions), as well as corresponding weighted average interest rates:    2016 2015  Average Balance Weighted Average Interest Rate Average Balance Weighted Average Interest Rate  $ 69.8 0.61 % $ 17.3 0.29 %  Term Loan s  Chugach ha d a term loan facilit y with CoBank , evidenced by the 2011 CoBank Note, which was governed by the Amended and Restated Master Loan Agreement dated January 19, 2011 , and secured by the Second Amended and Restated Indenture (Indenture) . Chugach ha d $22.2 million and $24.9 million outstanding on this facility at June 30 , 2016, and December 31, 2015, respectively.  On June 30, 2016 , Chugach entered into another term loan facility with CoBank, evidenced by the 2016 CoBank Note, which is governed by the Second Amended and Restated Master Loan Agreement dated June 30, 2016, and secured by the Indenture. Chugach had $45.6 million outstanding on this facility at June 30, 2016. On July 13, 2016, Chugach used commercial paper to pay off the $22.2 million balance on the 2011 CoBank Note.  Debt Issuance Costs  The following table outlines debt issuance costs associated with long-term obligations, excluding current installments, at June 30, 2016.    Long-term Obligations Unamortized Debt Issuance Costs  2011 Series A Bonds $ 210,999,998 $ 1,414,754  2012 Series A Bonds 194,250,000 1,151,655  2016 CoBank Note 41,952,000 235,504  $ 447,201,998 $ 2,801,913  The following table outlines debt issuance costs associated with long-term obligations, excluding current installments, at December 31, 2015.     Long-term Obligations Unamortized Debt Issuance Costs  2011 Series A Bonds $ 221,666,665 $ 1,482,791  2012 Series A Bonds 205,000,000 1,198,106  2011 CoBank Note 22,241,852 0  $ 448,908,517 $ 2,680,897 

Recent Accounting Pronouncement

Recent Accounting Pronouncements	6 Months Ended
	Jun. 30, 2016
Recent Accounting Pronouncements [Abstract]
Recent Accounting Pronouncements	6. RECENT ACCOUNTING PRONOUNCEMENTS  Issued and adopted:  ASC Update 2015-03 “ Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs ”  In April 2015, the FASB issued ASC Update 2015-03, “Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs.” ASC Update 2015 -03 revises the presentation guidance for debt issuance costs related to a recognized debt liability. The effect of this update is to present the debt issuance costs as a direct deduction to the liability on the balance sheet and retrospective application is required. This update does not change the recognition and measurement guidance for debt issuance costs. This update is effective for fiscal years beginning after December 15, 2015, and interim periods within those years , with early adoption permitted. Chugach began application of ASC 2015-03 with the fiscal year beginning January 1, 2016. Adoption did not have a material effect on its results of operations, financial position, and cash flows.  ASC Update 2015-15 “ Interest – Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements ”  In September 2015, the FASB issued ASC Update 2015-15, “Interest – Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements.” ASC Update 2015-15 amends guidance related to the presentation and subsequent measurement of debt issuance costs associated with line-of-credit arrangements for SEC reporting. This update is effective for fiscal years beginning after December 15, 2015, and interim periods beginning after December 15, 2016, with early adoption permitted . Chugach began application of ASC 2015-15 with the fiscal year beginning January 1, 2016 . Adoption did not have a material effect on its results of operations, financial position, and cash flows.  Adoption of the above guidance was applied retrospectively and reduced deferred charges and long-term debt by the unamortized debt issuance c osts of $ 2.8 million and $2.7 million at June 30, 2016, and December 31, 2015, respectively.  Issued, not yet adopted:  ASC Update 2014-09 “ Revenue from Contracts with Customers (Topic 606) ” and ASC 2014-14 “ Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date ”  In May 2014, the FASB issued ASC Update 2014-09, “Revenue from Contracts with Customers (Topic 606).” ASC Update 2014 -09 provides guidance for the recognition, measurement and disclosure of revenue related to the transfer of promised goods or services to customers. This update was effective for fiscal years beginning after December 15, 2016, for which early application wa s prohibited. However, i n August 2015, the FASB issued ASC Update 2014-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date,” defer ring the effective date of ASC Update 2014-09 to fiscal years beginning after December 15, 2017, and permit ting early adoption of this update, but only for annual reporting periods beginning after December 15, 2016, and interim reporting periods within that reporting period . The standard permits the use of either the retrospective or cumulative effect transition method. Chugach has not yet selected a transition method and is evaluating the effect on its results of operations, financial position, and cash flows.  ASC Update 2016-08 “Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net)”  In March 2016, the FASB issued ASC Update 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net).” ASC Update 2016-08 clarifies the implementation guidance in Topic 606 on principal versus agent considerations. This update affects the guidance in ASC Update 2014-09 and follows the same effective date and transition requirements. Chugach has not yet selected a transition method and is evaluating the effect on its results of operations, financial position, and cash flows.  ASC Update 2016-10 “ Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing ”  In April 2016, the FASB issued ASC Update 2016-10, “Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing.” ASC Update 2016-10 clarifies the guidance in Topic 606 on identifying the performance obligations and licensing implementation. This Update affects the guidance in ASC 2014-09 and follows the same effective date and transition requirements. Chugach has not yet selected a transition method and is evaluating the effect on its results of operations, financial position, and cash flows.  ASC Update 2016-11 “ Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Update 2014-09 and 2014-06 Pursuant to Staff Announcements at the March 3, 2016, EITF Meeting (SEC Update) ”  In May 2016, the FASB issued ASC Update 2016-11, “Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Update 2014-09 and 2014-06 Pursuant to Staff Announcements at the March 3, 2016, EITF Meeting (SEC Update).” ASC 2016-11 rescinds and supersedes SEC guidance previously governing revenue and expense recognition for freight services in process, accounting for shipping and handling fees and costs, consideration given by a vendor to a customer, and gas-balancing arrangem e nts. This update affects the guidance in ASC Update 2014-09 and 2014-06 and follows the same effective date and transition requirements. Chugach has not yet selected a transition method and is still evaluating the effect on its results of operations, financial position, and cash flows.  ASC Update 2016-12 “ Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients ”  In May 2016, the FASB issued ASC Update 2016-12, “Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients.” ASC 2016-12 clarifies the collectability criterion in the assessment of contracts with customers, the presentation of sales taxes and other similar taxes collected from customers, the measurement date to be used on noncash consideration included in contracts with customers, and contract modifications at transition. This Update affects the guidance in ASC Update 2014-09 and follows the same effective date and transition requirements. Chugach has not yet selected a transition method and is still evaluating the effect on its results of operations, financial position, and cash flows.  ASC Update 2016-01 “ Financial Instruments – Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities ”  In January 2016, the FASB issued ASC Update 2016-01, “Financial Instruments – Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” ASC Update 2016-01 amends guidance related to certain aspects of the recognition, measurement, presentation and disclosure of financial instruments. This update is effective for fiscal years beginning after December 15, 2018, and interim periods beginning after December 15, 2019, with early adoption not permitted with certain exceptions. Chugach will begin application of ASC 2016-01 with the annual report for the year ended December 31, 2019. Adoption is not expected to have a material effect on its results of operations, financial position, and cash flows.  ASC Update 2016-02 “ Leases (Topic 842): Section A – Leases: Amendments to the FASB Accounting Standards Codification; Section B – Conforming Amendments Related to Leases: Amendments to the FASB Accounting Standards Codification; Section C – Background Information and Basis for Conclusions ”  In February 2016, the FASB issued ASC Update 2016-02, “Leases (Topic 842): Section A – Leases: Amendments to the FASB Accounting Standards Codification; Section B – Conforming Amendments Related to Leases: Amendments to the FASB Accounting Standards Codification; Section C – Background Information and Basis for Conclusions.” ASC Update 2016-02 amends guidance related to the recognition, measurement, presentation and disclosure of leases for lessors and lessees. This update is effective for fiscal years beginning after December 15, 2018, including the interim periods within those years, with early adoption permitted. Chugach will begin application of ASC 2016-02 on January 1, 2019. Chugach is evaluating the effect on its results of operations, financial position, and cash flows.  ASC Update 2016-13 “ Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments ”  In June 2016, the FASB issued ASC Update 2016-13, “Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” ASC Update 2016-13 revised the criteria for the measurement, recognition, and reporting of credit losses on financial instruments to be recognized when expected. This update is effective for fiscal years beginning after December 15, 2019, including the interim periods within those years, with early adoption permitted for fiscal years beginning after December 15, 2018, including interim periods within those years. Chugach will begin application of ASC 2016-13 on January 1, 2020. Adoption is not expected to have a material effect on its results of operations, financial position, and cash flows. 

Fair Values Of Assets And Liabi

Fair Values Of Assets And Liabilities	6 Months Ended
	Jun. 30, 2016
Fair Values Of Assets And Liabilities [Abstract]
Fair Values Of Assets And Liabilities	7. FAIR VALUES 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.  Chugach had no Level 1 or Level 2 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.  Fair Value of BRU  Upon acquisition, a fair value analysis was performed on the BRU assets and the ARO assumed as part of the acquisition. The fair value estimate used the discounted cash flow method assuming an estimated useful life of 18 years with 27 Bcf of proven developed producing reserves and using Chugach’s BRU financing rate as the credit adjusted risk free rate. The fair value of the BRU assets acquired and the ARO assumed was recorded on the acquisition date.  Fair Value of Financial Instruments  The estimated fair values (in thousands) of long-term obligations included in the financial statements at June 30 , 201 6 , are as follows:    Measurement Carrying Value Fair Value  2011 CoBank Note Level 2 $ 22,242 $ 22,242  2011 Series A Bonds Level 2 221,667 241,702  2012 Series A Bonds Level 2 205,000 220,235  2016 CoBank Note Level 2 45,600 44,973  Long-term obligations (including current installments) $ 494,509 $ 529,152 

Environmental Matters

Environmental Matters	6 Months Ended
	Jun. 30, 2016
Environmental Matters [Abstract]
Environmental Matters	8. ENVIRONMENTAL MATTERS  Since January 1, 2007, transformer manufacturers have been required to meet the US Department of Energy (DOE) efficiency levels as defined by the Energy Act of 2005 (Energy Act) for all “Distribution Transformers.” As of January 1, 2016, the specific efficiency levels are increasing from the original “TP1” levels to the new “DOE-2016” levels. The Energy Act mandates specific types of low voltage dry-type transformers manufactured and sold in the USA to have efficiencies as defined by the 10 CFR Part 431 standard when loaded to 35% of maximum capacity. Chugach is in the process of evaluating our transformer specifications and will make modifications as necessary with our alliance transformer manufacturers to ensure DOE-2016 is met. At this time a small increase in capital costs is anticipated along with a reduction in energy losses.  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. On August 3, 2015, the EPA released the final 111(d) regulation language aimed at reducing emissions of carbon dioxide (CO 2 ) from existing power plants that provide electricity for utility customers. In the final rule, the EPA took the approach of making individual states responsible for the development and implementation of plans to reduce the rate of CO 2 emissions from the power sector. The EPA initially applied the final rule to 47 of the contiguous states. At this time, Alaska, Hawaii, Vermont, Washington D.C. and two U.S. territories are not bound by the regulation. Alaska may be required to comply at some future date. On February 9, 2016 the U.S. Supreme Court issued a stay on the proposed EPA 111(d) regulations until the DC Circuit decides the case, or until the disposition of a petition to the Supreme Court on the issue. The EPA 111(d) regulation, in its current form, is not expected to have a material effect on Chugach’s financial condition, results of operations, or cash flows. While Chugach cannot predict the implementation of any additional new law or regulation, or the limitations thereof, it is possible that new laws or regulations could increase capital and operating costs. Chugach has obtained or applied for all Clean Air Act permits currently required for the operation of 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. Chugach does not believe that compliance with these statutes and regulations to date has had a material impact on its financial condition, results of operation or cash flows. However, the implementation of any additional new law or regulation, or the limitations thereof, or changes in or new interpretations of laws or regulations could result in significant additional capital or operating expenses. Chugach monitors proposed new regulations and existing regulation changes through industry associations and professional organizations . 

Beluga River Unit

Beluga River Unit	6 Months Ended
	Jun. 30, 2016
Beluga River Unit [Abstract]
Beluga River Unit	9. BELUGA RIVER UNIT  On February 4, 2016 , Chugach entered into an agreement entitled, “Purchase and Sale Agreement between ConocoPhillips Alaska, Inc. and Municipality of Anchorage d/b/a Municipal Light & Power and Chugach Electric Association, Inc.” The Purchase and Sale Agreement transfers COP’s working interest in the BRU to Chugach and ML&P. The total purchase price was $152 million, with Chugach’s portion totaling $44.2 million. Chugach’s interest in the BRU is to reduce the cost of electric service to its retail and wholesale members by securing an additional long-term supply of natural gas to meet on-going generation requirements. The acquisition complements existing gas supplies and is expected to provide greater fuel diversity at an effective annual cost that is $2 million to $3 million less than alternative sources of gas in the Cook Inlet region.  Under the joint bid arrangement, Chugach’s ownership of COP’s working interest is 30% and ML&P’s ownership is 70% . The ownership shares include the attendant rights and privileges of all gas and oil resources, including 15,500 lease acres ( 8,200 in Unit / Participating Area and 7,300 held by Unit), Sterling and Beluga producing zones, and COP’s 67% working interest in deep oil resources. On April 21, 2016, the acquisition was approved by the RCA (see “ Note 5 – Regulatory Matters – Beluga River Unit ”) and the transaction closed on April 22, 2016 .  Chugach had a firm gas supply contract with COP, as previously discussed under “ Note 10 – Commitments and Contingencies – Commitments - Fuel Supply Contracts ”. In addition to Chugach, COP had contractual gas sales obligations to ENSTAR through 2017 . These contracts were assumed by ML&P and Chugach on the basis of ownership share.  The BRU is located on the western side of Cook Inlet, approximately 35 miles from Anchorage, and is an established natural gas field that was originally discovered in 1962. The BRU was jointly owned ( one -third) by COP, Hilcorp , and ML&P . Following the acquisition, ML&P’s ownership of the BRU increased to approximately 56.7% , Hilcorp’s ownership remained unchanged at 33.3% , and Chugach’s ownership is 10.0% .  Chugach’s interest in the BRU is insignificant to the BRU as a whole and compared to Chugach’s operations prior to the acquisition. As such, Chugach has not provided supplemental pro forma financial information. Since the BRU activities are limited to the extraction of natural gas, Chugach is following the guidance provided in ASC 932-810-45-1 (Extractive Activities-Oil and Gas – Consolidation – Other Presentation Matters) and will record its pro rata share of the assets, liabilities, revenues and expenses of the BRU.  Chugach recorded the acquisition at fair value. The allocation of the purchase price is considered preliminary, pending receipt of the final valuation report which is expected during 2016. The table below outlines the acquisition allocation recorded at June 30, 2016.     Amount  Utility Plant:  Proved Developed Reserves $ 33,983,293  Proved Undeveloped Reserves 10,200,000  Asset Retirement Obligation 3,523,409  Utility plant 47,706,702  Cost of removal obligation (3,523,409)  Cash Consideration $ 44,183,293  Acquisition costs are recorded as deferred charges on Chugach’s balance sheet because Chugach believes it is probable the RCA will allow them to be collected through rates, and totaled $1.4 million at June 30, 2016. These charges are amortized over the estimated life of the BRU and recognized as depreciation and amortization on Chugach’s statement of operations.  Each of the BRU participants has a right to take their interest of the gas produced. Parties that take less than their interest of the field’s output may either accept a cash settlement for their underlift or take their underlifted gas in future years. As part of the BRU acquisition, Chugach acquired 30% of COP’s underlift, which was 69,099 Mcf at acquisition and 68,354 Mcf at June 30, 2016. Chugach has opted to take the cumulative underlift in gas in the future and will record the gas as fuel expense on the statement of operations when received.  The revenue generated by Chugach’s interest in the BRU operations is primarily associated with the gas sold to ENSTAR, pursuant to the aforementioned contract due to expire December 31, 2017 . Chugach recognized revenue from the BRU in the amount of $0.8 million through June 30, 2016.  Chugach records depreciation, depletion and amortization on BRU assets based on units of production. As of June 30, 2016, Chugach lifted 0.9 Bcf resulting in approximately 26.1 Bcf remaining in Chugach’s proven developed reserves . Prior to the acquisition, COP was the contracted operator of the BRU . Following the acquisition , Hilcorp temporarily assumed operations under an agreement similar to that previously held by COP. A final operator agreement is expected during the fourth quarter of 2016. In addition to the operator fees to Hilcorp, other BRU expenses include royalty expense, interest on long-term debt, and estimated property tax. All expenses other than depreciation, depletion and amortization and interest on long-term debt are included as fuel expense on Chugach’s statement of operations. Chugach has applied and qualified for a small producer tax credit, provided by the State of Alaska, resulting in an estimate of no liability for production taxes. The revenue in excess of expenses less the allowed TIER from BRU operations is adjusted through Chugach’s fuel and purchased power adjustment process.

Commitments And Contingencies

Commitments And Contingencies	6 Months Ended
	Jun. 30, 2016
Commitments And Contingencies [Abstract]
Commitments And Contingencies	10. 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. Chugach establishes reserves when a particular contingency is probable and calculable . Chugach has not accrued for any contingency at June 30, 2016, as it does not consider any contingency to be probable nor calculable. Chuga ch faces contingencies that are reasonably possible to occur; however, they cannot currently be estimated.  Concentrations  Approximately 70 percent of Chugach’s employees are members of the IBEW. Chugach has three CBA’s with the IBEW. Chugach also has an agreement with the HERE. All three IBEW CBA’s have been renewed through June 30, 2017 . The HERE contract was renewed through June 30, 2016 . This contract will remain in effect until negotiations conclude, which are currently scheduled for the fourth quarter of 2016.  Chugach was the principal supplier of power under an Interim Power Sales Agr eement with MEA. Including the fuel component, this contract represented $26.2 million of sales revenue through its expiration on April 30, 2015 .  Commitments  Fuel Supply Contracts  Chugach has fuel supply contracts with various producers at market terms. A gas supply contract between Chugach and ConocoPhillips Alaska, Inc. and ConocoPhillips, Inc. (collectively “ConocoPhillips”), was approved by the RCA effective August 21, 2009 . Th is contract began provid ing gas in 2010 and will terminate December 31, 2016 . The total amount of gas under th is contract is estimated to be 62 Bcf. This contract was assumed by Chugach and ML&P as part of the BRU acquisition, on the basis of ownership share. As such, Chugach pays ML&P for 70% of gas purchased under this contract. Chugach entered into a gas contract with Hilcorp effective January 1, 2015 , to provide gas through March 31, 2018 . On September 15, 2014, the RCA approved an amendment to the Hilcorp gas purchase agreement extending gas delivery and subsequently filling 100 percent of Chugach’s needs through March 31, 2019 . On September 8, 2015 , the RCA approved another amendment to the Hilcorp gas purchase agreement extending the term of the agreement, thus filling up to 100 percent of Chugach’s needs through March 31, 2023 . The total amount of gas under this contract is estimated to be 60 Bcf. All of the production is expected to come from Cook Inlet, Alaska. The terms of the ML&P (previously under ConocoPhillips ) and Hilcorp agreements require Chugach to manage the natural gas transportation over the connecting pipeline systems. Chugach has gas transportation agreements with ENSTAR Natural Gas Company (ENSTAR) and Hilcorp.  Patronage Capital  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 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) and accepted by the RCA on August 7, 2007. HEA’s patronage capital was $7.9 million at June 30, 2016, and December 31, 2015, and is classified as patronage capital payable on Chugach’s balance sheet.  In an agreement reached in May 2014 with MEA, capital credits retired to MEA are classified as patronage capital payable on Chugach’s balance sheet. MEA’s patronage capital payable was $3.2 million at June 30, 2016, and December 31, 2015.  Legal Proceedings  Chugach has certain litigation matters and pending claims that arise in the ordinary course of Chugach’s business. In the opinion of management, none of these matters, individually or in the aggregate, is or are likely to have a material adverse effect on Chugach’s results of operations, financial condition or cash flows.

Significant Accounting Polici15

Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2016
Significant Accounting Policies [Abstract]
Management Estimates	a. Management Estimates  In preparing the financial statements in conformity with U.S. 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 liability, deferred charges and credits, unbilled revenue, estimated useful life of utility plant, cost of removal and asset retirement obligation (ARO), purchase price allocation for Beluga River Unit (BRU), and remaining proved BRU reserves. Actual results could differ from those estimates.
Full Cost Method	b. Full Cost Method  Pursuant to Accounting Standards Codification (ASC) 932-360-25, “Extractive Activities-Oil and Gas – Property, Plant and Equipment – Recognition”, Chugach has elected the Full C ost method, rather than the Successful Efforts method, to account for exploration and development costs of gas reserves. This is the first time Chugach has invested in oil or gas activities, so there is no prior policy of using the Successful Efforts method.
Depreciation, Depletion And Amortization (DD&A)	c. Depreciation, Depletion and Amortization (DD&A)  Chugach records DD&A expense on the BRU assets based on units of production using the following formula: ten percent of the total production from the BRU as provided by the operator divided by ten percent of the estimated remaining proved reserves (in Mcf) in the field multiplied by Chugach’s total assets in the BRU.
Asset Retirement Obligation (ARO)	d. Asset Retirement Obligation (ARO)  Chugach calculated and recorded an Asset Retirement Obligation associated with the BRU. Chugach uses its BRU financing rate as its credit adjusted risk free rate and the expected cash flow approach to calculate the fair value of the ARO liability. The ARO asset is depreciated using the DD&A formula outlined above. The ARO liability is accreted using the interest method of allocation.
Regulation	e. 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. Chugach’s regulated rates are established to recover all of the specific costs of providing electric service. In each rate filing, rates are set at levels to recover all of the specific allowable costs and those rates are then collected from retail and wholesale customers. The regulatory assets or liabilities are then reduced as the cost or credit is reflected in earnings and rates.
Income Taxes	f. 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 six month periods ended June 30, 2016 and 2015 was in compliance with that provision.  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.
Restricted Cash Equivalents	g. Restricted Cash Equivalents  Restricted cash equivalents include funds on deposit for future workers’ compensation claims, which amounted to $2.8 million at June 30, 2016, and December 31, 2015.
Accounts Receivable	h. Accounts Receivable  Included in accounts receivable are invoiced amounts to ML&P for their proportionate share of current Southcentral Power Project (SPP) costs, which amounted to $1.1 million at June 30, 2016, and December 31, 2015. 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 $0.2 million at December 31, 2015. At June 30, 2016, accounts receivable also includes $0.3 million from BRU operations primarily associated with gas sales to ENSTAR.
Fuel Stock	i. Fuel Stock  Fuel Stock is the weighted average cost of fuel injected into the Cook Inlet Natural Gas Storage Alaska (CINGSA). Chugach’s fuel balance in storage amounted to $7.4 million and $7.1 million at June 30, 2016, and December 31, 2015, respectively.
Corrections	h. Corrections  For the period ended June 30, 2016, Chugach recorded the following correction for the period ended June 30, 2015:  A correction representing the cash received from customers for the undergrounding ordinance, included in net receipts on consumer advances for construction, previously reported as other current liabilities. The impact of this correction was a decrease in cash provided by operating activities and cash used in financing activities of $1.7 million for the six months ended June 30, 2015.

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2016
Debt [Abstract]
Schedule Of Average Commercial Paper Balances Outstanding And Weighted Average Interest Rates	   2016 2015  Average Balance Weighted Average Interest Rate Average Balance Weighted Average Interest Rate  $ 69.8 0.61 % $ 17.3 0.29 % 
Schedule Of Debt Issuance Costs Associated With Long-Term Obligations	The following table outlines debt issuance costs associated with long-term obligations, excluding current installments, at June 30, 2016.    Long-term Obligations Unamortized Debt Issuance Costs  2011 Series A Bonds $ 210,999,998 $ 1,414,754  2012 Series A Bonds 194,250,000 1,151,655  2016 CoBank Note 41,952,000 235,504  $ 447,201,998 $ 2,801,913  The following table outlines debt issuance costs associated with long-term obligations, excluding current installments, at December 31, 2015.     Long-term Obligations Unamortized Debt Issuance Costs  2011 Series A Bonds $ 221,666,665 $ 1,482,791  2012 Series A Bonds 205,000,000 1,198,106  2011 CoBank Note 22,241,852 0  $ 448,908,517 $ 2,680,897 

Fair Values Of Assets And Lia17

Fair Values Of Assets And Liabilities (Tables)	6 Months Ended
	Jun. 30, 2016
Fair Values Of Assets And Liabilities [Abstract]
Schedule Of Estimated Fair Value Of Long-Term Obligations Included In Financial Statements	   Measurement Carrying Value Fair Value  2011 CoBank Note Level 2 $ 22,242 $ 22,242  2011 Series A Bonds Level 2 221,667 241,702  2012 Series A Bonds Level 2 205,000 220,235  2016 CoBank Note Level 2 45,600 44,973  Long-term obligations (including current installments) $ 494,509 $ 529,152 

Beluga River Unit (Tables)

Beluga River Unit (Tables)	6 Months Ended
	Jun. 30, 2016
Beluga River Unit [Abstract]
Schedule Of Acquisition Allocation	   Amount  Utility Plant:  Proved Developed Reserves $ 33,983,293  Proved Undeveloped Reserves 10,200,000  Asset Retirement Obligation 3,523,409  Utility plant 47,706,702  Cost of removal obligation (3,523,409)  Cash Consideration $ 44,183,293 

Description Of Business (Detail

Description Of Business (Details)	6 Months Ended
	Jun. 30, 2016miagreement
Description Of Business [Line Items]
Electrification area | mi	400
Matanuska Electric Association, Inc. [Member]
Description Of Business [Line Items]
Power contracts expiration date	Apr. 30, 2015
Golden Valley Electric Association, Inc. [Member]
Description Of Business [Line Items]
Power contracts expiration date	Mar. 31, 2015
International Brotherhood of Electrical Workers [Member]
Description Of Business [Line Items]
Number of collective bargaining agreements	3
Percentage of employees belonging to unions	70.00%
Expiration date of collective bargaining agreements	Jun. 30, 2017
Hotel Employees and Restaurant Employees [Member]
Description Of Business [Line Items]
Number of collective bargaining agreements	1
Expiration date of collective bargaining agreements	Jun. 30, 2016

Significant Accounting Polici20

Significant Accounting Policies (Details) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Significant Accounting Policies [Line Items]
Numerator percentage of total production	10.00%
Denominator percentage of estimated remaining proved reserves	10.00%
Accounts receivable	$ 25,133,242		$ 28,232,930
Fuel stock	7,378,360		7,063,541
Cash provided by operating activities	20,686,492	$ 39,135,606
Cash used in financing activities	37,131,426	(33,004,583)
ML&P For Fuel And South Central Power Project Costs [Member]
Significant Accounting Policies [Line Items]
Accounts receivable	1,100,000		1,100,000
Alaska Energy Authority For Grant [Member]
Significant Accounting Policies [Line Items]
Accounts receivable			200,000
BRU Operations For Gas Sales [Member]
Significant Accounting Policies [Line Items]
Accounts receivable	300,000
Funds On Deposit [Member]
Significant Accounting Policies [Line Items]
Restricted cash equivalents	$ 2,800,000		$ 2,800,000
Restatement Adjustment [Member]
Significant Accounting Policies [Line Items]
Cash provided by operating activities		(1,700,000)
Cash used in financing activities		$ 1,700,000

Regulatory Matters (Details)

Regulatory Matters (Details)	Jul. 08, 2016USD ($)	Jul. 01, 2016USD ($)	Dec. 04, 2015MMcf	Feb. 13, 2015USD ($)	Jan. 30, 2015MMcf	Aug. 31, 2016USD ($)	Jan. 31, 2016USD ($)	Jul. 31, 2015a	Apr. 30, 2015	Jun. 30, 2016$ / McfeMMcf	Dec. 31, 2015
Other Commitments [Line Items]
Proposed increase (decrease) in rates				$ 21,300,000
Proposed percentage increase (decrease) in rates				20.00%
Approved percentage increase (decrease) in rates							(0.50%)
Times interest earned ratio							1.35				1.30
Times interest earned ratio margin increase per year							$ 1,000,000
Simplified rate filing response period										45 days
Matanuska Electric Association, Inc. [Member]
Other Commitments [Line Items]
Term of dispatch services										1 year
Expiration date of Dispatch Services Agreement										Mar. 31, 2016
Commencement date of Gas Dispatch Agreement										Apr. 1, 2016
Expiration date of Gas Dispatch Agreement										Mar. 31, 2017
Extension date of Gas Dispatch Agreement										Mar. 31, 2018
Optional extension date of Gas Dispatch Agreement										Mar. 31, 2019
Power contracts expiration date										Apr. 30, 2015
City Of Seward [Member]
Other Commitments [Line Items]
Power contracts expiration date										Dec. 31, 2016
Power contracts extension date										Dec. 31, 2021
Automatic extension term										5 years
Written notice period prior to expiration date										1 year
ConocoPhillips (COP) [Member]
Other Commitments [Line Items]
Acres of exploration prospects | a								5,700
Minimum [Member]
Other Commitments [Line Items]
Approved percentage increase (decrease) in rates									2.00%
Maximum [Member]
Other Commitments [Line Items]
Approved percentage increase (decrease) in rates									5.00%
Subsequent Event [Member]
Other Commitments [Line Items]
Proposed increase (decrease) in rates		$ 4,800,000
Proposed percentage increase (decrease) in rates		4.20%
Subsequent Event [Member] | City Of Seward [Member]
Other Commitments [Line Items]
Refunds issued	$ 28,000
Subsequent Event [Member] | Retail Customers [Member]
Other Commitments [Line Items]
Proposed percentage increase (decrease) in rates		2.50%
Refunds issued						$ 750,000
CINGSA [Member]
Other Commitments [Line Items]
Total volume of natural gas found | MMcf					14,500
Approved volume of natural gas for commercial sale | MMcf			2,000
Percentage of proceeds allocated			13.00%
Term of notice preceding gas sales										30 days
CINGSA [Member] | Minimum [Member]
Other Commitments [Line Items]
Proposed volume of natural gas for commercial sale | MMcf										2,000
FSS [Member]
Other Commitments [Line Items]
Percentage of proceeds allocated			87.00%
Beluga River Unit [Member]
Other Commitments [Line Items]
Date of Purchase and Sale Agreement										Feb. 4, 2016
Initial gas transfer price | $ / Mcfe										5.88

Debt (Narrative) (Details)

Debt (Narrative) (Details) - USD ($)	Jul. 13, 2016	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Debt Instrument [Line Items]
Commercial paper		$ 34,000,000		$ 20,000,000
Repayments of long-term debt		$ 24,115,980	$ 23,889,777
Commercial Paper [Member] | Minimum [Member]
Debt Instrument [Line Items]
Commercial paper repricing term		1 day
Commercial Paper [Member] | Maximum [Member]
Debt Instrument [Line Items]
Commercial paper repricing term		270 days
Revolving Line Of Credit [Member]
Debt Instrument [Line Items]
Line of credit, maximum borrowing capacity		$ 50,000,000
Line of credit, outstanding balance				$ 0
Line of credit, borrowing rate description		The borrowing rate is calculated using the total rate per annum and may be fixed by NRUCFC.
Line of credit, borrowing rate		2.50%		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		Oct. 12, 2017
Amended And Unsecured Credit Agreement [Member] | Unsecured Credit Facility [Member]
Debt Instrument [Line Items]
Line of credit, maximum borrowing capacity		$ 100,000,000
Line of credit, borrowing rate description		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, expiration date		Nov. 17, 2016
Commercial paper, basis points facility fee on variable rate		0.175%
Amended And Unsecured Credit Agreement [Member] | Unsecured Credit Facility [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Commercial paper, basis points on variable rate		1.075%
Credit Agreement [Member] | Unsecured Credit Facility [Member]
Debt Instrument [Line Items]
Line of credit, maximum borrowing capacity		$ 150,000,000
Line of credit, borrowing rate description		one month LIBOR plus 90.0 basis points, along with a 10.0 basis points facility fee (based on an A/A2/A unsecured debt rating)
Line of credit, expiration date		Jun. 13, 2021
Line of credit, commencement date		Jun. 13, 2016
Commercial paper, basis points facility fee on variable rate		0.10%
Credit Agreement [Member] | Unsecured Credit Facility [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Commercial paper, basis points on variable rate		0.90%
2011 CoBank Note [Member] | Term Loan Facility [Member]
Debt Instrument [Line Items]
Note outstanding balance		$ 22,200,000		$ 24,900,000
2016 CoBank Note [Member] | Term Loan Facility [Member]
Debt Instrument [Line Items]
Note commencement date		Jun. 30, 2016
Note outstanding balance		$ 45,600,000
Subsequent Event [Member] | 2011 CoBank Note [Member] | Term Loan Facility [Member]
Debt Instrument [Line Items]
Repayments of long-term debt	$ 22,200,000

Debt (Schedule Of Average Comme

Debt (Schedule Of Average Commercial Paper Balances Outstanding And Weighted Average Interest Rates) (Details) - Commercial Paper [Member] - USD ($) $ in Millions	3 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Short-term Debt [Line Items]
Average Balance	$ 69.8	$ 17.3
Weighted Average Interest Rate	0.61%	0.29%

Debt (Schedule Of Debt Issuance

Debt (Schedule Of Debt Issuance Costs Associated With Long-Term Obligations) (Details) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term Obligations	$ 447,201,998	$ 448,908,517
Unamortized Debt Issuance Costs	2,801,913	2,680,897
Term Loan Facility [Member] | 2011 Series A Bonds [Member]
Debt Instrument [Line Items]
Long-term Obligations	210,999,998	221,666,665
Unamortized Debt Issuance Costs	1,414,754	1,482,791
Term Loan Facility [Member] | 2012 Series A Bonds [Member]
Debt Instrument [Line Items]
Long-term Obligations	194,250,000	205,000,000
Unamortized Debt Issuance Costs	1,151,655	1,198,106
Term Loan Facility [Member] | 2011 CoBank Note [Member]
Debt Instrument [Line Items]
Long-term Obligations		22,241,852
Unamortized Debt Issuance Costs		$ 0
Term Loan Facility [Member] | 2016 CoBank Note [Member]
Debt Instrument [Line Items]
Long-term Obligations	41,952,000
Unamortized Debt Issuance Costs	$ 235,504

Recent Accounting Pronounceme25

Recent Accounting Pronouncements (Details) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Recent Accounting Pronouncements [Abstract]
Unamortized debt issuance costs	$ 2,801,913	$ 2,680,897

Fair Values Of Assets And Lia26

Fair Values Of Assets And Liabilities (Narrative) (Details) MMcf in Thousands	6 Months Ended
	Jun. 30, 2016USD ($)MMcf
Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value, assets	$ 0
Fair value, liabilities	0
Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value, assets	0
Fair value, liabilities	$ 0
Beluga River Unit [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Estimated useful life	18 years
Proved developed producing reserves | MMcf	27

Fair Values Of Assets And Lia27

Fair Values Of Assets And Liabilities (Schedule Of Estimated Fair Value Of Long-Term Obligations Included In Financial Statements) (Details) $ in Thousands	Jun. 30, 2016USD ($)
Carrying Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term obligations (including current installments)	$ 494,509
Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term obligations (including current installments)	529,152
2011 CoBank Note [Member] | Term Loan Facility [Member] | Level 2 [Member] | Carrying Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term obligations (including current installments)	22,242
2011 CoBank Note [Member] | Term Loan Facility [Member] | Level 2 [Member] | Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term obligations (including current installments)	22,242
2011 Series A Bonds [Member] | Term Loan Facility [Member] | Level 2 [Member] | Carrying Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term obligations (including current installments)	221,667
2011 Series A Bonds [Member] | Term Loan Facility [Member] | Level 2 [Member] | Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term obligations (including current installments)	241,702
2012 Series A Bonds [Member] | Term Loan Facility [Member] | Level 2 [Member] | Carrying Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term obligations (including current installments)	205,000
2012 Series A Bonds [Member] | Term Loan Facility [Member] | Level 2 [Member] | Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term obligations (including current installments)	220,235
2016 CoBank Note [Member] | Term Loan Facility [Member] | Level 2 [Member] | Carrying Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term obligations (including current installments)	45,600
2016 CoBank Note [Member] | Term Loan Facility [Member] | Level 2 [Member] | Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term obligations (including current installments)	$ 44,973

Beluga River Unit (Narrative) (

Beluga River Unit (Narrative) (Details)	Feb. 04, 2016USD ($)a	Jun. 30, 2016USD ($)MMcf	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)miMMcf	Jun. 30, 2015USD ($)	Apr. 22, 2016MMcf
Business Acquisition [Line Items]
Revenue		$ 44,622,517	$ 47,697,820	$ 94,872,652	$ 122,670,937
Beluga River Unit [Member]
Business Acquisition [Line Items]
Date of Purchase and Sale Agreement				Feb. 4, 2016
Total purchase price	$ 152,000,000
Cash consideration		$ 44,183,293		$ 44,183,293
Working interest ownership percentage	30.00%	10.00%		10.00%
Number of lease acres | a	15,500
Number of lease acres in Unit / Participating Area | a	8,200
Number of lease acres held by Unit | a	7,300
Closing date of Purchase and Sale Agreement				Apr. 22, 2016
Number of miles from Anchorage | mi				35
Acquisition costs		$ 1,400,000		$ 1,400,000
Amount of gas acquired | MMcf		68,354		68,354		69,099
Expiration date of gas sales				Dec. 31, 2017
Revenue				$ 800,000
Lifted amount of gas in proven developed reserves | MMcf		900		900
Remaining amount of gas in proven developed reserves | MMcf		26,100		26,100
Municipal Light & Power [Member] | Beluga River Unit [Member]
Business Acquisition [Line Items]
Working interest ownership percentage	70.00%	56.70%		56.70%		33.30%
ConocoPhillips (COP) [Member] | Beluga River Unit [Member]
Business Acquisition [Line Items]
Working interest ownership percentage						33.30%
ConocoPhillips (COP) [Member] | Deep Oil Resources [Member]
Business Acquisition [Line Items]
Working interest ownership percentage	67.00%
Hilcorp Alaska, LLC [Member] | Beluga River Unit [Member]
Business Acquisition [Line Items]
Working interest ownership percentage		33.30%		33.30%		33.30%
Minimum [Member] | Beluga River Unit [Member]
Business Acquisition [Line Items]
Effective annual cost savings				$ (2,000,000)
Maximum [Member] | Beluga River Unit [Member]
Business Acquisition [Line Items]
Effective annual cost savings				$ (3,000,000)
ENSTAR [Member] | ConocoPhillips (COP) [Member]
Business Acquisition [Line Items]
Expiration year of Gas Sale and Purchase Agreement				2,017

Beluga River Unit (Schedule Of

Beluga River Unit (Schedule Of Acquisition Allocation) (Details) - Beluga River Unit [Member]	Jun. 30, 2016USD ($)
Business Acquisition [Line Items]
Proved Developed Reserves	$ 33,983,293
Proved Undeveloped Reserves	10,200,000
Asset Retirement Obligation	3,523,409
Utility plant	47,706,702
Cost of removal obligation	(3,523,409)
Cash Consideration	$ 44,183,293

Commitments And Contingencies (

Commitments And Contingencies (Details)	3 Months Ended		4 Months Ended	6 Months Ended
	Jun. 30, 2016USD ($)MMcf	Jun. 30, 2015USD ($)	Apr. 30, 2015USD ($)	Jun. 30, 2016USD ($)agreementMMcf	Jun. 30, 2015USD ($)	Apr. 22, 2016	Feb. 04, 2016	Dec. 31, 2015USD ($)
Other Commitments [Line Items]
Contingency accruals	$ 0			$ 0
Operating revenues	44,622,517	$ 47,697,820		94,872,652	$ 122,670,937
Patronage capital payable	11,108,071			$ 11,108,071				$ 11,108,071
Matanuska Electric Association, Inc. [Member]
Other Commitments [Line Items]
Operating revenues			$ 26,200,000
Power contracts expiration date				Apr. 30, 2015
Patronage capital payable	3,200,000			$ 3,200,000				3,200,000
Homer Electric Association, Inc. [Member]
Other Commitments [Line Items]
Power contracts expiration date				Dec. 31, 2013
Number of years to return patronage capital after expiration of power agreement				5 years
Patronage capital payable	$ 7,900,000			$ 7,900,000				$ 7,900,000
ConocoPhillips (COP) [Member]
Other Commitments [Line Items]
Commencement date of long term contract for purchase of gas supply				Aug. 21, 2009
Expiration date of long term contract for purchase of gas supply				Dec. 31, 2016
Estimated amount of gas under contract | MMcf	62,000			62,000
Hilcorp Alaska - Cook Inlet [Member]
Other Commitments [Line Items]
Commencement date of long term contract for purchase of gas supply				Jan. 1, 2015
Expiration date of long term contract for purchase of gas supply				Mar. 31, 2018
Estimated amount of gas under contract | MMcf	60,000			60,000
Percentage of met natural gas needs				100.00%
Initial extension date of long term contract for purchase of gas supply				Mar. 31, 2019
Subsequent extension date of long term contract for purchase of gas supply				Mar. 31, 2023
Beluga River Unit [Member]
Other Commitments [Line Items]
Operating revenues				$ 800,000
Estimated amount of gas under contract | MMcf	26,100			26,100
Working interest ownership percentage	10.00%			10.00%			30.00%
Beluga River Unit [Member] | Municipal Light & Power [Member]
Other Commitments [Line Items]
Working interest ownership percentage	56.70%			56.70%		33.30%	70.00%
International Brotherhood of Electrical Workers [Member]
Other Commitments [Line Items]
Percentage of employees belonging to unions	70.00%			70.00%
Number of collective bargaining agreements | agreement				3
Expiration date of collective bargaining agreements				Jun. 30, 2017
Hotel Employees and Restaurant Employees [Member]
Other Commitments [Line Items]
Number of collective bargaining agreements | agreement				1
Expiration date of collective bargaining agreements				Jun. 30, 2016