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Document and Entity Information Document - shares	9 Months Ended
Document and Entity Information Document - shares	Sep. 30, 2014	Oct. 31, 2014
Document Information [Line Items]
Entity Registrant Name	BLACK HILLS CORP /SD/
Entity Central Index Key	0001130464
Document Type	10-Q
Document Period End Date	Sep. 30, 2014
Amendment Flag	false
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		44,655,369
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No

Condensed Statements of Income (unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenue	$ 272,087	$ 259,907	$ 1,015,493	$ 920,404
Utilities -
Fuel, purchased power and cost of natural gas sold	84,674	71,503	416,473	338,848
Operations and maintenance	64,245	66,061	201,546	196,728
Non-regulated energy operations and maintenance	20,170	20,484	63,852	62,703
Depreciation, depletion and amortization	37,463	36,135	110,258	106,068
Taxes - property, production and severance	11,082	10,068	32,462	30,517
Other operating expenses	49	90	323	1,091
Total operating expenses	217,683	204,341	824,914	735,955
Operating income	54,404	55,566	190,579	184,449
Interest charges -
Interest expense incurred (including amortization of debt issuance costs, premiums and discounts and realized settlements on interest rate swaps)	(17,919)	(23,840)	(53,665)	(70,881)
Allowance for funds used during construction - borrowed	319	347	845	831
Capitalized interest	231	273	734	811
Unrealized gain (loss) on interest rate swaps, net	0	3,144	0	29,393
Interest income	575	565	1,541	1,325
Allowance for funds used during construction - equity	297	85	828	327
Other income (expense), net	261	318	1,262	1,197
Total other income (expense), net	(16,236)	(19,108)	(48,455)	(36,997)
Income (loss) before earnings (loss) of unconsolidated subsidiaries and income taxes	38,168	36,458	142,124	147,452
Equity in earnings (loss) of unconsolidated subsidiaries	0	0	(1)	(86)
Income tax benefit (expense)	(11,332)	(13,334)	(47,349)	(50,527)
Net income (loss) available for common stock	$ 26,836	$ 23,124	$ 94,774	$ 96,839
Earnings (loss) per share, Basic -
Total income (loss) per share, Basic	$ 0.60	$ 0.52	$ 2.14	$ 2.19
Earnings (loss) per share, Diluted -
Total income (loss) per share, Diluted	$ 0.60	$ 0.52	$ 2.13	$ 2.18
Weighted Average Number of Shares Outstanding:
Basic	44,415	44,201	44,382	44,143
Diluted	44,608	44,457	44,584	44,395
Dividends declared per share of common stock	$ 0.39	$ 0.38	$ 1.17	$ 1.14

Condensed Consolidated Statement of Comprehensive Income (unaudited) Statement - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Net income (loss) available for common stock	$ 26,836	$ 23,124	$ 94,774	$ 96,839
Other comprehensive income (loss), net of tax:
Fair value adjustments on derivatives designated as cash flow hedges (net of tax (expense) benefit of $(1,840) and $964 for the three months ended 2014 and 2013 and $582 and $(93) for the nine months ended 2014 and 2013, respectively)	3,145	(2,083)	(1,071)	134
Reclassification adjustments for cash flow hedges settled and included in net income (loss) (net of tax (expense) benefit of $(732) and $(586) for the three months ended 2014 and 2013 and $(1,931) and $(1,469) for the nine months ended 2014 and 2013, respectively)	1,328	1,426	3,511	3,095
Benefit plan liability adjustments - net gain (loss) (net of tax of $0 and $0 for the three months ended 2014 and 2013 and $2 and $0 for the nine months ended 2014 and 2013, respectively)	0	0	(2)	0
Benefit plan liability tax adjustments - net gain (loss)	0	0	(394)	0
Benefit plan liability adjustments - prior service cost (net of tax of $0 and $0 for the three months ended 2014 and 2013 and $(90) and $0 for the nine months ended 2014 and 2013, respectively)	0	0	164	0
Reclassification adjustments of benefit plan liability - prior service cost (net of tax of $17 and $22 for the three months ended 2014 and 2013 and $60 and $66 for the nine months ended 2014 and 2013, respectively)	(31)	(41)	(110)	(123)
Reclassification adjustments of benefit plan liability - net gain (loss) (net of tax of $(86) and $(242) for the three months ended 2014 and 2013 and $(262) and $(729) for the nine months ended 2014 and 2013, respectively)	160	458	485	1,361
Other comprehensive income (loss), net of tax	4,602	(240)	2,583	4,467
Comprehensive income (loss) available for common stock	31,438	22,884	97,357	101,306
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent, Parenthetical Disclosures
Fair value adjustment on derivatives designated as cash flow hedges, (tax) benefit	(1,840)	964	582	(93)
Reclassification adjustments of cash flow hedges settled and included in net income, (tax) benefit	(732)	(586)	(1,931)	(1,469)
Benefit plan liability adjustments net gain, (tax) benefit	0	0	2	0
Benefit plan liability adjustments prior service cost, (tax) benefit	0	0	(90)	0
Reclassification adjustment of benefit plan prior service cost included in net income, (tax) benefit	17	22	60	66
Reclassification adjustment of benefit plan liabilities actuarial gain (loss), (tax) benefit	$ (86)	$ (242)	$ (262)	$ (729)

Condensed Consolidated Balance Sheets (unaudited) Statement - USD ($) $ in Thousands	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
Current assets:
Cash and cash equivalents	$ 11,939	$ 7,841	$ 13,637
Restricted cash and equivalents	1,918	2	6,782
Accounts receivable, net	123,399	177,573	114,137
Materials, supplies and fuel	105,726	88,478	95,230
Derivative assets, current	0	717	126
Income tax receivable, net	1,268	1,460	4,539
Deferred income tax assets, net, current	34,756	18,889	37,163
Regulatory assets, current	68,444	24,451	30,208
Other current assets	26,502	25,877	27,075
Total current assets	373,952	345,288	328,897
Investments	17,144	16,697	16,612
Property, plant and equipment	4,493,696	4,259,445	4,152,097
Less accumulated depreciation and depletion	(1,338,509)	(1,269,148)	(1,258,450)
Total property, plant and equipment, net	3,155,187	2,990,297	2,893,647
Other assets:
Goodwill	353,396	353,396	353,396
Intangible assets, net	3,231	3,397	3,453
Regulatory assets, non-current	140,422	138,197	183,119
Derivative assets, non-current	0	0	0
Other assets, non-current	29,930	27,906	22,116
Total other assets, non-current	526,979	522,896	562,084
TOTAL ASSETS	4,073,262	3,875,178	3,801,240
Current liabilities:
Accounts payable	100,444	130,416	77,077
Accrued liabilities	163,374	151,277	152,911
Derivative liabilities, current	3,397	3,474	65,944
Regulatory liabilities, current	828	10,727	14,707
Notes payable	184,000	82,500	138,300
Current maturities of long-term debt	275,000	0	255,694
Total current liabilities	727,043	378,394	704,633
Long-term debt, net of current maturities	1,107,519	1,396,948	955,979
Deferred credits and other liabilities:
Deferred income tax liabilities, net, non-current	506,166	432,287	403,772
Derivative liabilities, non-current	3,273	5,614	11,388
Regulatory liabilities, non-current	118,856	109,429	131,730
Benefit plan liabilities	108,924	111,479	169,448
Other deferred credits and other liabilities	144,089	133,279	133,341
Total deferred credits and other liabilities	881,308	792,088	849,679
Commitments and contingencies (See Notes 7, 8, 13, 14 and 15)
Stockholders’ equity:
Common stock $1 par value; 100,000,000 shares authorized; issued 44,696,670; 44,550,239; and 44,532,245 shares, respectively	44,697	44,550	44,532
Additional paid-in capital	746,575	742,344	740,209
Retained earnings	582,800	540,244	539,030
Treasury stock, at cost – 41,552; 50,877; and 41,127 shares, respectively	(1,841)	(1,968)	(1,801)
Accumulated other comprehensive income (loss)	(14,839)	(17,422)	(31,021)
Total stockholders’ equity	1,357,392	1,307,748	1,290,949
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$ 4,073,262	$ 3,875,178	$ 3,801,240

Condensed Consolidated Balance Sheets (unaudited) Parantheticals - $ / shares	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
Common Stock, Par Per Share	$ 1.00	$ 1.00	$ 1.00
Common Stock, Shares Issued	44,696,670	44,550,239	44,532,245
Treasury Stock, Shares	41,552	50,877	47,127
Common Stock, Shares Authorized	100,000,000	100,000,000	100,000,000
Common Stock, Shares Outstanding	44,655,118	44,499,362	44,485,118

Condensed Consoldiated Statement of Cash Flows (unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Operating activities:
Net income (loss) available for common stock	$ 94,774	$ 96,839
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	110,258	106,068
Deferred financing cost amortization	1,608	3,209
Derivative fair value adjustments	2,136	275
Stock compensation	6,978	9,100
Unrealized (gain) loss on interest rate swaps, net	0	(29,393)
Deferred income taxes	48,007	54,865
Employee benefit plans	11,109	16,644
Other adjustments, net	2,016	9,434
Changes in certain operating assets and liabilities:
Materials, supplies and fuel	(17,248)	(12,522)
Accounts receivable, unbilled revenue and other operating assets	(61)	28,762
Accounts payable and other current liabilities	(14,307)	(23,774)
Contributions to defined benefit pension plans	(10,200)	(12,500)
Other operating activities, net	4,087	4,759
Net cash provided by (used in) operating activities	239,157	251,766
Investing activities:
Property, plant and equipment additions	(290,299)	(239,485)
Proceeds from sale of assets	22,342	0
Other investing activities	(2,364)	2,846
Net cash provided by (used in) investing activities	(270,321)	(236,639)
Financing activities:
Dividends paid on common stock	(52,218)	(50,678)
Common stock issued	2,393	3,606
Short-term borrowings - issuances	396,250	269,600
Short-term borrowings - repayments	(294,750)	(408,300)
Long-term debt - issuances	0	275,000
Long-term debt - repayments	(12,200)	(106,180)
Other financing activities	(4,213)	0
Net cash provided by (used in) financing activities	35,262	(16,952)
Net change in cash and cash equivalents	4,098	(1,825)
Cash and Cash Equivalents:
Cash and cash equivalents, beginning of period	7,841	15,462
Cash and cash equivalents, end of period	$ 11,939	$ 13,637

Management's Statement	9 Months Ended
Management's Statement	Sep. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Management's Statement [Text Block]	MANAGEMENT’S STATEMENT The unaudited Condensed Consolidated Financial Statements included herein have been prepared by Black Hills Corporation (together with our subsidiaries the “Company,” “us,” “we,” or “our”), pursuant to the rules and regulations of the SEC. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been condensed or omitted pursuant to such rules and regulations; however, we believe that the footnotes adequately disclose the information presented. These Condensed Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and the notes thereto included in our 2013 Annual Report on Form 10-K filed with the SEC. We conduct our operations through the following reportable segments: Electric Utilities, Gas Utilities, Power Generation, Coal Mining and Oil and Gas. Our reportable segments are based on our method of internal reporting, which generally segregates the strategic business groups due to differences in products, services and regulation. All of our operations and assets are located within the United States. Accounting methods historically employed require certain estimates as of interim dates. The information furnished in the accompanying Condensed Consolidated Financial Statements reflects all adjustments, including accruals, which are, in the opinion of management, necessary for a fair presentation of the September 30, 2014, December 31, 2013, and September 30, 2013 financial information and are of a normal recurring nature. Certain industries in which we operate are highly seasonal, and revenue from, and certain expenses for, such operations may fluctuate significantly among quarterly periods. Demand for electricity and natural gas is sensitive to seasonal cooling, heating and industrial load requirements, as well as changes in market price. In particular, the normal peak usage season for electric utilities is June through August while the normal peak usage season for gas utilities is November through March. Significant earnings variances can be expected between the Gas Utilities segment’s peak and off-peak seasons. Due to this seasonal nature, our results of operations for the three and nine months ended September 30, 2014 and September 30, 2013, and our financial condition as of September 30, 2014, December 31, 2013, and September 30, 2013, are not necessarily indicative of the results of operations and financial condition to be expected as of or for any other period. All earnings per share amounts discussed refer to diluted earnings per share unless otherwise noted. Recently Issued and Adopted Accounting Standards We have implemented all new accounting pronouncements that are in effect and may impact our financial statements and do not believe that there are any other new accounting pronouncements that have been issued that might have a material impact on our financial position, results of operations, or cash flows. Revenue from Contracts with Customers, ASU 2014-09 In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers. The standard provides companies with a single model for use in accounting for revenue arising from contracts with customers and supersedes current revenue recognition guidance, including industry-specific revenue guidance. The core principle of the model is to recognize revenue when control of the goods or services transfers to the customer, as opposed to recognizing revenue when the risks and rewards transfer to the customer under the existing revenue guidance. ASU 2014-09 is effective for annual and interim reporting periods beginning after December 15, 2016 and early adoption is not permitted. We are currently assessing the impact, if any, that ASU 2014-09 will have on our financial position, results of operations or cash flows.

Business Segment Information

9 Months Ended

Sep. 30, 2014

Segment Reporting Information, Additional Information [Abstract]

Business Segment Information [Text Block]

BUSINESS SEGMENT INFORMATION

Segment information and Corporate activities included in the accompanying Condensed Consolidated Statements of Income (Loss) were as follows (in thousands):



Three Months Ended September 30, 2014	External Operating Revenue		Inter-company Operating Revenue			Net Income (Loss)
Utilities:
Electric	$	171,395	$	3,156		$	18,154
Gas	78,735		—			1,597
Non-regulated Energy:
Power Generation	1,602		20,419			7,829
Coal Mining	6,884		8,689			2,638
Oil and Gas	13,471		—			(3,110		)
Corporate activities	—		—			(272		)
Inter-company eliminations	—		(32,264		)	—
Total	$	272,087	$	—		$	26,836



Three Months Ended September 30, 2013	External Operating Revenue		Inter-company Operating Revenue			Net Income (Loss)
Utilities:
Electric	$	169,401	$	2,003		$	15,097
Gas	67,792		—			(1,450		)
Non-regulated Energy:
Power Generation	1,575		20,393			6,707
Coal Mining	6,713		8,604			2,142
Oil and Gas	14,426		—			(1,682		)
Corporate activities ^(a)	—		—			2,310
Inter-company eliminations	—		(31,000		)	—
Total	$	259,907	$	—		$	23,124



Nine Months Ended September 30, 2014	External Operating Revenues		Intercompany Operating Revenues			Net Income (Loss)
Utilities:
Electric	$	508,230	$	10,307		$	44,156
Gas	440,571		—			28,289
Non-regulated Energy:
Power Generation	4,138		62,211			23,096
Coal Mining	19,085		26,637			7,118
Oil and Gas	43,469		—			(6,792		)
Corporate activities	—		—			(1,093		)
Inter-company eliminations	—		(99,155		)	—
Total	$	1,015,493	$	—		$	94,774



Nine Months Ended September 30, 2013	External Operating Revenues		Intercompany Operating Revenues			Net Income (Loss)
Utilities:
Electric	$	482,222	$	9,844		$	38,063
Gas	373,440		—			20,225
Non-regulated Energy:
Power Generation	3,628		58,825			17,382
Coal Mining	19,530		23,688			5,180
Oil and Gas	41,584		—			(3,699		)
Corporate activities ^(a)	—		—			19,688
Inter-company eliminations	—		(92,357		)	—
Total	$	920,404	$	—		$	96,839

__________


(a)	Corporate activities include a $2.0 million and a $19 million after-tax non-cash mark-to-market gain on certain interest rate swaps for the three and nine months ended September 30, 2013, respectively.

Segment information and Corporate balances included in the accompanying Condensed Consolidated Balance Sheets were as follows (in thousands):



Total Assets (net of inter-company eliminations) as of:	September 30, 2014		December 31, 2013		September 30, 2013
Utilities:
Electric ^(a)	$	2,671,601	$	2,525,947	$	2,464,123
Gas	827,069		805,617		757,746
Non-regulated Energy:
Power Generation^(a)	64,359		95,692		102,331
Coal Mining	74,130		78,825		82,155
Oil and Gas	330,781		288,366		264,785
Corporate activities	105,322		80,731		130,100
Total assets	$	4,073,262	$	3,875,178	$	3,801,240

__________


(a)	The PPA under which Black Hills Colorado IPP provides generation to support Colorado Electric customers from the Pueblo Airport Generation Station is accounted for as a capital lease. As such, assets owned by our Power Generation segment are recorded at Colorado Electric under accounting for a capital lease.

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-Section 50
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+ Details

Accounts Receivable

9 Months Ended

Sep. 30, 2014

Receivables [Abstract]

Accounts Receivable [Text Block]

ACCOUNTS RECEIVABLE

Following is a summary of Accounts receivable, net included in the accompanying Condensed Consolidated Balance Sheets (in thousands) as of:



	Accounts		Unbilled		Less Allowance for			Accounts
September 30, 2014	Receivable, Trade		Revenue		Doubtful Accounts			Receivable, net
Electric Utilities	$	53,717	$	21,485	$	(724	)	$	74,478
Gas Utilities	23,409		13,218		(740		)	35,887
Power Generation	1,368		—		—			1,368
Coal Mining	2,563		—		—			2,563
Oil and Gas	7,657		—		(13		)	7,644
Corporate	1,459		—		—			1,459
Total	$	90,173	$	34,703	$	(1,477	)	$	123,399



	Accounts		Unbilled		Less Allowance for			Accounts
December 31, 2013	Receivable, Trade		Revenue		Doubtful Accounts			Receivable, net
Electric Utilities	$	52,437	$	23,823	$	(666	)	$	75,594
Gas Utilities	49,162		41,195		(558		)	89,799
Power Generation	1,722		—		—			1,722
Coal Mining	1,711		—		—			1,711
Oil and Gas	8,156		—		(13		)	8,143
Corporate	604		—		—			604
Total	$	113,792	$	65,018	$	(1,237	)	$	177,573



	Accounts		Unbilled		Less Allowance for			Accounts
September 30, 2013	Receivable, Trade		Revenue		Doubtful Accounts			Receivable, net
Electric Utilities	$	49,254	$	20,153	$	(648	)	$	68,759
Gas Utilities	20,693		11,877		(542		)	32,028
Power Generation	3		—		—			3
Coal Mining	2,677		—		—			2,677
Oil and Gas	8,463		—		(19		)	8,444
Corporate	2,226		—		—			2,226
Total	$	83,316	$	32,030	$	(1,209	)	$	114,137

- Definition

The entire disclosure for claims held for amounts due a entity, excluding financing receivables. Examples include, but are not limited to, trade accounts receivables, notes receivables, loans receivables. Includes disclosure for allowance for credit losses.

+ References + Details

Regulatory Accounting

9 Months Ended

Sep. 30, 2014

Regulatory Assets and Liabilities Disclosure [Abstract]

Regulatory Accounting [Text Block]

REGULATORY ACCOUNTING

We had the following regulatory assets and liabilities (in thousands):



	Maximum	As of		As of		As of
	Amortization (in years)	September 30, 2014		December 31, 2013		September 30, 2013
Regulatory assets
Deferred energy and fuel cost adjustments - current^(a)(d)	1	$	26,211	$	16,775	$	17,925
Deferred gas cost adjustments and natural gas price derivatives^(a)(d)	7	49,870		12,366		16,845
AFUDC^(b)	45	12,411		12,315		12,398
Employee benefit plans ^(c)	13	64,908		67,059		114,386
Environmental^(a)	subject to approval	1,314		1,800		1,800
Asset retirement obligations^(a)	44	3,282		3,266		3,262
Bond issue cost^(a)	24	3,311		3,419		3,454
Renewable energy standard adjustment ^(a)	5	12,007		14,186		14,936
Flow through accounting^(c)	35	25,157		20,916		19,222
Other regulatory assets^(a)	15	10,395		10,546		9,099
		$	208,866	$	162,648	$	213,327

Regulatory liabilities
Deferred energy and gas costs^(a)	1	$	5,535	$	11,708	$	14,032
Employee benefit plans^(c)	13	34,409		34,431		60,707
Cost of removal^(a)	44	71,362		64,970		62,069
Other regulatory liabilities^(c)	25	8,378		9,047		9,629
		$	119,684	$	120,156	$	146,437

__________


(a)	Recovery of costs, but we are not allowed a rate of return.


(b)	In addition to recovery of costs, we are allowed a rate of return.


(c)	In addition to recovery or repayment of costs, we are allowed a return on a portion of this amount or a reduction in rate base, respectively.

(d)

Our deferred energy, fuel cost, and gas cost adjustments represent the cost of electricity and gas delivered to our electric and gas utility customers that is either higher or lower than current rates and will be recovered or refunded in future rates. Increases in the current year balances as of September 30, 2014 are primarily due to higher natural gas prices driven by demand and market conditions during our peak winter heating season. Our electric and gas utilities file periodic quarterly, semi-annual, and/or annual filings to recover these costs based on the respective cost mechanisms approved by their applicable state utility commissions.

Materials, Supplies and Fuel

9 Months Ended

Sep. 30, 2014

Inventory, Net [Abstract]

Materials, Supplies and Fuel [Text Block]

MATERIALS, SUPPLIES AND FUEL

The following amounts by major classification are included in Materials, supplies and fuel in the accompanying Condensed Consolidated Balance Sheets (in thousands) as of:



	September 30, 2014		December 31, 2013		September 30, 2013
Materials and supplies	$	52,682	$	50,196	$	50,564
Fuel - Electric Utilities	7,108		6,213		6,384
Natural gas in storage held for distribution	45,936		32,069		38,282
Total materials, supplies and fuel	$	105,726	$	88,478	$	95,230

Earnings Per Share

9 Months Ended

Sep. 30, 2014

Earnings Per Share [Abstract]

Earnings Per Share [Text Block]

EARNINGS PER SHARE

A reconciliation of share amounts used to compute Earnings (loss) per share in the accompanying Condensed Consolidated Statements of Income (loss) is as follows (in thousands):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2014		2013		2014		2013

Net income (loss) available for common stock	$	26,836	$	23,124	$	94,774	$	96,839

Weighted average shares - basic	44,415		44,201		44,382		44,143
Dilutive effect of:
Equity compensation	193		256		202		252

Weighted average shares - diluted	44,608		44,457		44,584		44,395

The following outstanding securities were not included in the computation of diluted earnings per share as their effect would have been anti-dilutive (in thousands):



	Three Months Ended September 30,		Nine Months Ended September 30,
	2014	2013	2014	2013

Equity compensation	99	—	75	9
Anti-dilutive shares	99	—	75	9

Notes Payable and Current Maturities of Long-term Debt

9 Months Ended

Sep. 30, 2014

Debt Disclosure [Abstract]

Notes Payable [Text Block]

NOTES PAYABLE AND CURRENT MATURITIES OF LONG-TERM DEBT

We had the following short-term debt outstanding in the accompanying Condensed Consolidated Balance Sheets (in thousands) as of:



	September 30, 2014				December 31, 2013				September 30, 2013
	Balance Outstanding		Letters of Credit		Balance Outstanding		Letters of Credit		Balance Outstanding		Letters of Credit
Revolving Credit Facility	$	184,000	$	31,726	$	82,500	$	22,100	$	138,300	$	53,137

Revolving Credit Facility

On May 29, 2014, we amended our $500 million corporate Revolving Credit Facility agreement to extend the term through May 29, 2019. This facility is substantially similar to the former agreement, which includes an accordion feature that allows us, with the consent of the administrative agent and issuing agents, to increase the capacity of the facility to $750 million. Borrowings continue to be available under a base rate or various Eurodollar rate options. The interest costs associated with the letters of credit or borrowings and the commitment fee under the Revolving Credit Facility are determined based upon our most favorable Corporate credit rating from S&P and Moody’s for our unsecured debt. Based on our credit ratings, the margins for base rate borrowings, Eurodollar borrowings, and letters of credit were 0.125%, 1.125%, and 1.125%, respectively, from May 29, 2014 through September 30, 2014; a reduction of 0.25% for each method of borrowing as compared to the previous arrangement. Borrowings under the facility are primarily Eurodollar based. A commitment fee is charged on the unused amount of the Revolving Credit Facility and was 0.175% based on our credit rating, a reduction of 0.025% compared to the prior arrangement.

Current Maturities of Long-Term Debt

As of September 30, 2014, our $275 million Corporate term loan due June 19, 2015 is classified as Current maturities of long-term debt.

Debt Covenants

Our Revolving Credit Facility and our Term Loan require compliance with the following financial covenant at the end of each quarter:



	As of September 30, 2014	Covenant Requirement
Recourse Leverage Ratio	54%	Less than	65%

As of September 30, 2014, we were in compliance with this covenant.

Risk Management Activities (Notes)

9 Months Ended

Sep. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Risk Management Activities

RISK MANAGEMENT ACTIVITIES

Our activities in the regulated and non-regulated energy sectors expose us to a number of risks in the normal operation of our businesses. Depending on the activity, we are exposed to varying degrees of market risk and credit risk. To manage and mitigate these identified risks, we have adopted the Black Hills Corporation Risk Policies and Procedures as discussed in our 2013 Annual Report on Form 10-K.

Market Risk

Market risk is the potential loss that might occur as a result of an adverse change in market price or rate. We are exposed to the following market risks including, but not limited to:


•	Commodity price risk associated with our natural long position in crude oil and natural gas reserves and production; and our fuel procurement for certain of our gas-fired generation assets; and


•	Interest rate risk associated with our variable-rate debt.

Credit Risk

Credit risk is the risk of financial loss resulting from non-performance of contractual obligations by a counterparty.

For production and generation activities, we attempt to mitigate our credit exposure by conducting business primarily with high credit quality entities, setting tenor and credit limits commensurate with counterparty financial strength, obtaining master netting agreements, and mitigating credit exposure with less creditworthy counterparties through parental guarantees, prepayments, letters of credit, and other security agreements.

We perform ongoing credit evaluations of our customers and adjust credit limits based upon payment history and the customer’s current creditworthiness, as determined by review of their current credit information. We maintain a provision for estimated credit losses based upon historical experience and any specific customer collection issue that is identified.

As of September 30, 2014, our credit exposure included a $0.5 million exposure to non-investment grade energy marketing companies. The remainder of our credit exposure was concentrated primarily among retail utility customers, investment grade rated companies, cooperative utilities and federal agencies. Our derivative and hedging activities recorded in the accompanying Condensed Consolidated Balance Sheets, Condensed Consolidated Statements of Income (Loss) and Condensed Consolidated Statements of Comprehensive Income (Loss) are detailed below and in Note 9.

Oil and Gas

We produce natural gas and crude oil through our exploration and production activities. Our natural long positions, or unhedged open positions, result in commodity price risk and variability to our cash flows.

To mitigate commodity price risk and preserve cash flows, we primarily use OTC swaps, exchange traded futures and related options to hedge portions of our crude oil and natural gas production. We elect hedge accounting on these instruments. These transactions were designated at inception as cash flow hedges, documented under accounting standards for derivatives and hedging, and initially met prospective effectiveness testing. Effectiveness of our hedging position is evaluated at least quarterly.

The derivatives were marked to fair value and were recorded as Derivative assets or Derivative liabilities on the accompanying Condensed Consolidated Balance Sheets. The effective portion of the gain or loss on these derivatives for which we have elected cash flow hedge accounting is reported in AOCI in the accompanying Condensed Consolidated Balance Sheets and the ineffective portion, if any, is reported in Revenue in the accompanying Condensed Consolidated Statements of Income (Loss).

The contract or notional amounts, terms of our commodity derivatives, and the derivative balances for our Oil and Gas segment reflected on the Condensed Consolidated Balance Sheets were as follows (dollars in thousands) as of:



	September 30, 2014				December 31, 2013				September 30, 2013
	Crude Oil Futures, Swaps and Options		Natural Gas Futures and Swaps		Crude Oil Futures, Swaps and Options		Natural Gas Futures and Swaps		Crude Oil Futures, Swaps and Options		Natural Gas Futures and Swaps
Notional ^(a)	391,500		7,930,000		412,500		7,082,500		499,500		9,874,000
Maximum terms in months ^(b)	1		1		3		1		3		1
Derivative assets, current	$	—	$	—	$	55	$	—	$	13	$	113
Derivative assets, non-current	$	—	$	—	$	—	$	—	$	—	$	—
Derivative liabilities, current	$	—	$	—	$	—	$	—	$	98	$	52
Derivative liabilities, non-current	$	—	$	—	$	—	$	—	$	—	$	—

__________


(a)	Crude oil in Bbls, natural gas in MMBtus.


(b)	Refers to the tenor of the derivative instrument. Assets and liabilities are classified as current/non-current based on the production month hedged and the corresponding settlement of the derivative instrument.

A $0.7 million gain is included in AOCI at September 30, 2014, and would be realized over the next 12 months if market prices remained equal to September 30, 2014 prices. Future realized gains or losses fluctuate with market prices.

Utilities

The operations of our utilities, including natural gas sold by our Gas Utilities and natural gas used for Electric Utility generation plants or those plants under PPAs where our Electric Utilities must provide the generation fuel (tolling agreements), expose our utility customers to volatility in natural gas prices. Therefore, as allowed or required by state utility commissions, we have entered into commission-approved hedging programs utilizing natural gas futures, options and basis swaps to reduce our customers’ underlying exposure to these fluctuations. These transactions are considered derivatives, and in accordance with accounting standards for derivatives and hedging, mark-to-market adjustments are recorded as Derivative assets or Derivative liabilities on the accompanying Condensed Consolidated Balance Sheets, net of balance sheet offsetting as permitted by GAAP. Unrealized and realized gains and losses, as well as option premiums and commissions on these transactions are recorded as Regulatory assets or Regulatory liabilities in the accompanying Condensed Consolidated Balance Sheets in accordance with state commission guidelines. When the related costs are recovered through our rates, the hedging activity is recognized in the Condensed Consolidated Statements of Income (Loss).

The contract or notional amounts and terms of the natural gas derivative commodity instruments held at our Utilities were as follows, as of:



	September 30, 2014		December 31, 2013		September 30, 2013
	Notional (MMBtus)	Maximum Term (months)^(a)	Notional (MMBtus)	Maximum Term (months)^(a)	Notional (MMBtus)	Maximum Term (months)^(a)
Natural gas futures purchased	16,290,000	74	17,930,000	84	14,010,000	74
Natural gas options purchased	7,070,000	6	3,890,000	8	6,810,000	6
Natural gas basis swaps purchased	12,025,000	63	14,785,000	60	9,790,000	63

__________

(a) Term reflects the maximum forward period hedged.

We had the following derivative balances related to the hedges in our Utilities reflected in our Condensed Consolidated Balance Sheets as of (in thousands):



	September 30, 2014		December 31, 2013		September 30, 2013
Derivative assets, current	$	—	$	662	$	—
Derivative assets, non-current	$	—	$	—	$	—
Derivative liabilities, non-current	$	—	$	—	$	—
Net unrealized (gain) loss included in Regulatory assets or Regulatory liabilities	$	7,470	$	7,567	$	10,652

Financing Activities

We entered into floating-to-fixed interest rate swap agreements to reduce our exposure to interest rate fluctuations associated with our floating rate debt obligations. The contract or notional amounts, terms of our interest rate swaps and the interest rate swaps balances reflected on the Condensed Consolidated Balance Sheets were as follows (dollars in thousands) as of:



	September 30, 2014			December 31, 2013			September 30, 2013
	Interest Rate Swaps^(a)			Interest Rate Swaps^(a)			Interest Rate Swaps^(b)			De-designated Interest Rate Swaps^(c)
Notional	$	75,000		$	75,000		$	150,000		$	250,000
Weighted average fixed interest rate	4.97		%	4.97		%	5.04		%	5.67		%
Maximum terms in years	2.25			3.00			3.25			0.25
Derivative liabilities, current	$	3,397		$	3,474		$	7,039		$	58,755
Derivative liabilities, non-current	$	3,273		$	5,614		$	11,388		$	—

__________


(a)	These swaps are designated to borrowings on our Revolving Credit Facility, and are priced using three-month LIBOR, matching the floating portion of the related debt.

(b)

At September 30, 2013, $75 million of these interest rate swaps was designated to borrowings on our Revolving Credit Facility and $75 million was designated to borrowings on our project financing debt at Black Hills Wyoming. These swaps were priced using three-month LIBOR, matching the floating portion of the related debt. The portion of the swaps that was designated to Black Hills Wyoming was settled during the fourth quarter of 2013 upon repayment of the Black Hills Wyoming project financing.


(c)	These swaps were settled during the fourth quarter of 2013.

Based on September 30, 2014, market interest rates and balances related to our interest rate swaps, a loss of approximately $3.4 million would be realized, reported in pre-tax earnings and reclassified from AOCI during the next 12 months. Estimated and actual realized gains or losses will change during future periods as market interest rates change.

Cash Flow Hedges

The impacts of cash flow hedges on our Condensed Consolidated Statements of Income (Loss) were as follows (in thousands):



Three Months Ended September 30, 2014
Derivatives in Cash Flow Hedging Relationships	Amount of Gain/(Loss) Recognized in AOCI Derivative (Effective Portion)		Location of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	Amount of Reclassified Gain/(Loss) from AOCI into Income (Effective Portion)			Location of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)
Interest rate swaps	$	152	Interest expense	$	(925	)		$	—
Commodity derivatives	4,833		Revenue	(1,135		)		—
Total	$	4,985		$	(2,060	)		$	—



Three Months Ended September 30, 2013
Derivatives in Cash Flow Hedging Relationships	Amount of Gain/(Loss) Recognized in AOCI Derivative (Effective Portion)			Location of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	Amount of Reclassified Gain/(Loss) from AOCI into Income (Effective Portion)			Location of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)
Interest rate swaps	$	(907	)	Interest expense	$	(1,844	)		$	—
Commodity derivatives	(2,140		)	Revenue	(168		)		—
Total	$	(3,047	)		$	(2,012	)		$	—



Nine Months Ended September 30, 2014
Derivatives in Cash Flow Hedging Relationships	Amount of Gain/(Loss) Recognized in AOCI Derivative (Effective Portion)			Location of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	Amount of Reclassified Gain/(Loss) from AOCI into Income (Effective Portion)			Location of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)
Interest rate swaps	$	(277	)	Interest expense	$	(2,745	)		$	—
Commodity derivatives	(1,376		)	Revenue	(2,697		)		—
Total	$	(1,653	)		$	(5,442	)		$	—



Nine Months Ended September 30, 2013
Derivatives in Cash Flow Hedging Relationships	Amount of Gain/(Loss) Recognized in AOCI Derivative (Effective Portion)		Location of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	Amount of Reclassified Gain/(Loss) from AOCI into Income (Effective Portion)			Location of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)
Interest rate swaps	$	141	Interest expense	$	(5,460	)		$	—
Commodity derivatives	86		Revenue	896				—
Total	$	227		$	(4,564	)		$	—

- Definition

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

+ References

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+ Details

Fair Value Measurements

9 Months Ended

Sep. 30, 2014

Fair Value Disclosures [Abstract]

Fair Value Measurements [Text Block]

FAIR VALUE MEASUREMENTS

Derivative Financial Instruments

The accounting guidance for fair value measurements requires certain disclosures about assets and liabilities measured at fair value. This guidance establishes a hierarchical framework for disclosing the observability of the inputs utilized in measuring assets and liabilities at fair value. Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement within the fair value hierarchy levels. We record transfers, if necessary, between levels at the end of the reporting period for all of our financial instruments. For additional information see Notes 1, 8 and 10 to the Consolidated Financial Statements included in our 2013 Annual Report on Form 10-K filed with the SEC.

Transfers into Level 3, if any, occur when significant inputs used to value the derivative instruments become less observable such as a significant decrease in the frequency and volume in which the instrument is traded, negatively impacting the availability of observable pricing inputs. Transfers out of Level 3, if any, occur when the significant inputs become more observable, such as when the time between the valuation date and the delivery date of a transaction becomes shorter, positively impacting the availability of observable pricing inputs.

Valuation Methodologies for Derivatives

Oil and Gas Segment:


•	The commodity option contracts for our Oil and Gas segment are valued using the market approach and can include calls and puts. Fair value was derived using quoted prices from third-party brokers for similar instruments as to quantity and timing. The prices are then validated through third-party sources and therefore support Level 2 disclosure.


•	The commodity basis swaps for our Oil and Gas segment are valued using the market approach with the instrument’s current forward price strip hedged for the same quantity and date and discounted based on the three-month LIBOR. We utilize observable inputs which support a Level 2 disclosure.

Utilities Segments:

•

The commodity contracts for our Utilities Segments, valued using the market approach, include exchange-traded futures, options and basis swaps (Level 2) and OTC basis swaps (Level 3) for natural gas contracts. For Level 2 assets and liabilities, fair value was derived using broker quotes validated by the Chicago Mercantile Exchange pricing for similar instruments. For Level 3 assets and liabilities, fair value was derived using average price quotes from the OTC contract broker and an independent third-party market participant because these instruments are not traded on an exchange.

Corporate Activities:

•

The interest rate swaps are valued using the market approach. We establish fair value by obtaining price quotes directly from the counterparty which are based on the floating three-month LIBOR curve for the term of the contract. The fair value obtained from the counterparty is then validated by utilizing a nationally recognized service that obtains observable inputs to compute fair value for the same instrument. In addition, the fair value for the interest rate swap derivatives includes a CVA component. The CVA considers the fair value of the interest rate swap and the probability of default based on the life of the contract. For the probability of a default component, we utilize observable inputs supporting a Level 2 disclosure by using our credit default spread, if available, or a generic credit default spread curve that takes into account our credit ratings.

Recurring Fair Value Measurements

There have been no significant transfers between Level 1 and Level 2 derivative balances. Amounts included in cash collateral and counterparty netting in the following tables represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions, netting of asset and liability positions permitted in accordance with accounting standards for offsetting as well as cash collateral posted with the same counterparties.

The following tables set forth by level within the fair value hierarchy our gross assets and gross liabilities and related offsetting as permitted by GAAP that were accounted for at fair value on a recurring basis for derivative instruments. A discussion of fair value of financial instruments is included in Note 10:



	As of September 30, 2014
	Level 1		Level 2		Level 3		Cash Collateral and Counterparty Netting			Total
	(in thousands)
Assets:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	—	$	—	$	—		$	—
Basis Swaps -- Oil	—		322		—		(322		)	—
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		1,545		—		(1,545		)	—
Commodity derivatives — Utilities	—		4,029		—		(4,029		)	—
Total	$	—	$	5,896	$	—	$	(5,896	)	$	—

Liabilities:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	—	$	—	$	—		$	—
Basis Swaps -- Oil	—		487		—		(487		)	—
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		865		—		(865		)	—
Commodity derivatives — Utilities	—		8,679		—		(8,679		)	—
Interest rate swaps	—		6,670		—		—			6,670
Total	$	—	$	16,701	$	—	$	(10,031	)	$	6,670



	As of December 31, 2013
	Level 1		Level 2		Level 3		Cash Collateral and Counterparty Netting			Total
	(in thousands)
Assets:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	—	$	—	$	—		$	—
Basis Swaps -- Oil	—		130		—		(75		)	55
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		815		—		(815		)	—
Commodity derivatives —Utilities	—		3,030		—		(2,368		)	662
Total	$	—	$	3,975	$	—	$	(3,258	)	$	717

Liabilities:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	—	$	—	$	—		$	—
Basis Swaps -- Oil	—		1,229		—		(1,229		)	—
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		531		—		(531		)	—
Commodity derivatives — Utilities	—		9,100		—		(9,100		)	—
Interest rate swaps	—		9,088		—		—			9,088
Total	$	—	$	19,948	$	—	$	(10,860	)	$	9,088



	As of September 30, 2013
	Level 1		Level 2		Level 3		Cash Collateral and Counterparty Netting			Total
	(in thousands)
Assets:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	2	$	—	$	—		$	2
Basis Swaps -- Oil	—		51		—		(40		)	11
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		1,752		—		(1,639		)	113
Commodity derivatives — Utilities	—		2,351		—		(2,351		)	—
Total	$	—	$	4,156	$	—	$	(4,030	)	$	126

Liabilities:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	142	$	—	$	(77	)	$	65
Basis Swaps -- Oil	—		1,318		—		(1,284		)	34
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		232		—		(181		)	51
Commodity derivatives — Utilities	—		10,747		—		(10,747		)	—
Interest rate swaps	—		83,142		—		(5,960		)	77,182
Total	$	—	$	95,581	$	—	$	(18,249	)	$	77,332

Fair Value Measures by Balance Sheet Classification

As required by accounting standards for derivatives and hedges, fair values within the following tables are presented on a gross basis reflecting the netting of asset and liability positions permitted in accordance with accounting standards for offsetting and under terms of our master netting agreements and the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions; however, the amounts do not include net cash collateral on deposit in margin accounts at September 30, 2014, December 31, 2013, and September 30, 2013, to collateralize certain financial instruments, which are included in Derivative assets and/or Derivative liabilities. Therefore, the balances are not indicative of either our actual credit exposure or net economic exposure. Additionally, the amounts below will not agree with the amounts presented on our Condensed Consolidated Balance Sheets, nor will they correspond to the fair value measurements presented in Note 8.

The following tables present the fair value and balance sheet classification of our derivative instruments (in thousands):



As of September 30, 2014
	Balance Sheet Location	Fair Value of Asset Derivatives		Fair Value of Liability Derivatives
Derivatives designated as hedges:
Commodity derivatives	Derivative assets — current	$	1,174	$	—
Commodity derivatives	Derivative assets — non-current	692		—
Commodity derivatives	Derivative liabilities — current	—		497
Commodity derivatives	Derivative liabilities — non-current	—		856
Interest rate swaps	Derivative liabilities — current	—		3,397
Interest rate swaps	Derivative liabilities — non-current	—		3,273
Total derivatives designated as hedges		$	1,866	$	8,023

Derivatives not designated as hedges:
Commodity derivatives	Derivative assets — current	$	—	$	—
Commodity derivatives	Derivative assets — non-current	—		—
Commodity derivatives	Derivative liabilities — current	—		48
Commodity derivatives	Derivative liabilities — non-current	—		4,602
Total derivatives not designated as hedges		$	—	$	4,650



As of December 31, 2013
	Balance Sheet Location	Fair Value of Asset Derivatives		Fair Value of Liability Derivatives
Derivatives designated as hedges:
Commodity derivatives	Derivative assets — current	$	248	$	—
Commodity derivatives	Derivative assets — non-current	698		—
Commodity derivatives	Derivative liabilities — current	—		1,541
Commodity derivatives	Derivative liabilities — non-current	—		219
Interest rate swaps	Derivative liabilities — current	—		3,474
Interest rate swaps	Derivative liabilities — non-current	—		5,614
Total derivatives designated as hedges		$	946	$	10,848

Derivatives not designated as hedges:
Commodity derivatives	Derivative assets — current	$	662	$	—
Commodity derivatives	Derivative assets — non-current	—		—
Commodity derivatives	Derivative liabilities — current	—		—
Commodity derivatives	Derivative liabilities — non-current	—		6,732
Total derivatives not designated as hedges		$	662	$	6,732



As of September 30, 2013
	Balance Sheet Location	Fair Value of Asset Derivatives		Fair Value of Liability Derivatives
Derivatives designated as hedges:
Commodity derivatives	Derivative assets — current	$	846	$	—
Commodity derivatives	Derivative assets — non-current	959		—
Commodity derivatives	Derivative liabilities — current	—		1,317
Commodity derivatives	Derivative liabilities — non-current	—		375
Interest rate swaps	Derivative liabilities — current	—		7,039
Interest rate swaps	Derivative liabilities — non-current	—		11,388
Total derivatives designated as hedges		$	1,805	$	20,119

Derivatives not designated as hedges:
Commodity derivatives	Derivative assets — current	$	—	$	—
Commodity derivatives	Derivative assets — non-current	—		—
Commodity derivatives	Derivative liabilities — current	—		1,795
Commodity derivatives	Derivative liabilities — non-current	—		6,601
Interest rate swaps	Derivative liabilities — current	—		64,715
Interest rate swaps	Derivative liabilities — non-current	—		—
Total derivatives not designated as hedges		$	—	$	73,111

Fair Value of Financial Instruments

9 Months Ended

Sep. 30, 2014

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments [Text Block]

FAIR VALUE OF FINANCIAL INSTRUMENTS

The estimated fair values of our financial instruments, excluding derivatives which are presented in Note 9, were as follows (in thousands) as of:



	September 30, 2014				December 31, 2013				September 30, 2013
	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
Cash and cash equivalents ^(a)	$	11,939	$	11,939	$	7,841	$	7,841	$	13,637	$	13,637
Restricted cash and equivalents ^(a)	$	1,918	$	1,918	$	2	$	2	$	6,782	$	6,782
Notes payable ^(a)	$	184,000	$	184,000	$	82,500	$	82,500	$	138,300	$	138,300
Long-term debt, including current maturities ^(b)	$	1,382,519	$	1,547,359	$	1,396,948	$	1,491,422	$	1,211,673	$	1,325,729

__________


(a)	Carrying value approximates fair value due to either the short-term length of maturity or variable interest rates that approximate prevailing market rates, and therefore is classified in Level 1 in the fair value hierarchy.


(b)	Long-term debt is valued based on observable inputs available either directly or indirectly for similar liabilities in active markets and therefore is classified in Level 2 in the fair value hierarchy.

- Definition

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

+ References + Details

Other Comprehensive Income (Loss)

9 Months Ended

Sep. 30, 2014

Other Comprehensive Income (Loss), Net of Tax [Abstract]

Other Comprehensive Income (Loss) [Text Block]

OTHER COMPREHENSIVE INCOME (LOSS)

The components of the reclassification adjustments, net of tax, included in Other Comprehensive Income (Loss) for the periods were as follows (in thousands):



	Location on the Condensed Consolidated Statements of Income (Loss)	Amount Reclassified from AOCI
		Three Months Ended						Nine Months Ended
		September 30, 2014			September 30, 2013			September 30, 2014			September 30, 2013
Gains (losses) on cash flow hedges:
Interest rate swaps	Interest expense	$	925		$	1,844		$	2,745		$	5,460
Commodity contracts	Revenue	1,135			168			2,697			(896		)
		2,060			2,012			5,442			4,564
Income tax	Income tax benefit (expense)	(732		)	(586		)	(1,931		)	(1,469		)
Reclassification adjustments related to cash flow hedges, net of tax		$	1,328		$	1,426		$	3,511		$	3,095

Amortization of defined benefit plans:
Prior service cost	Utilities - Operations and maintenance	$	(26	)	$	(31	)	$	(77	)	$	(93	)
	Non-regulated energy operations and maintenance	(22		)	(32		)	(93		)	(96		)

Actuarial gain (loss)	Utilities - Operations and maintenance	158			425			473			1,267
	Non-regulated energy operations and maintenance	88			275			274			823
		198			637			577			1,901
Income tax	Income tax benefit (expense)	(69		)	(220		)	(202		)	(663		)
Reclassification adjustments related to defined benefit plans, net of tax		$	129		$	417		$	375		$	1,238

Balances by classification included within Accumulated other comprehensive income (loss) on the accompanying Condensed Consolidated Balance Sheets are as follows (in thousands):



	Derivatives Designated as Cash Flow Hedges			Employee Benefit Plans			Total
Balance as of December 31, 2012	$	(15,713	)	$	(19,775	)	$	(35,488	)
Other comprehensive income (loss), net of tax	(1,193		)	457			(736		)
Balance as of March 31, 2013	(16,906		)	(19,318		)	(36,224		)
Other comprehensive income (loss), net of tax	5,079			364			5,443
Balance as of June 30, 2013	(11,827		)	(18,954		)	(30,781		)
Other comprehensive income (loss), net of tax	(657		)	417			(240		)
Ending Balance September 30, 2013	$	(12,484	)	$	(18,537	)	$	(31,021	)

Balance as of December 31, 2013	$	(7,133	)	$	(10,289	)	$	(17,422	)
Other comprehensive income (loss), net of tax	(1,478		)	311			(1,167		)
Balance as of March 31, 2014	(8,611		)	(9,978		)	(18,589		)
Other comprehensive income (loss), net of tax	(556		)	(296		)	(852		)
Balance as of June 30, 2014	(9,167		)	(10,274		)	(19,441		)
Other comprehensive income (loss), net of tax	4,473			129			4,602
Ending Balance Sept. 30, 2014	$	(4,694	)	$	(10,145	)	$	(14,839	)

- Definition

The entire disclosure for comprehensive income, which includes, but is not limited to, 1) the amount of income tax expense or benefit allocated to each component of other comprehensive income, including reclassification adjustments, 2) the reclassification adjustments for each classification of other comprehensive income and 3) the ending accumulated balances for each component of comprehensive income.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=28358780&loc=d3e689-108580

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=28358780&loc=SL7669619-108580

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 12
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Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
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-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=28358780&loc=d3e709-108580

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
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-Paragraph 11
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Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
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-Section 45
-Paragraph 14
-URI http://asc.fasb.org/extlink&oid=28358780&loc=d3e681-108580

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Reclassification Adjustments
-URI http://asc.fasb.org/extlink&oid=6522872

+ Details

Supplemental Disclosure of Cash Flow Information

9 Months Ended

Sep. 30, 2014

Supplemental Cash Flow Information [Abstract]

Supplemental Disclosure of Cash Flow Information [Text Block]

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION



Nine months ended	September 30, 2014			September 30, 2013
	(in thousands)
Non-cash investing and financing activities from continuing operations—
Property, plant and equipment acquired with accrued liabilities	$	52,484		$	47,214
Increase (decrease) in capitalized assets associated with asset retirement obligations	$	(2,785	)	$	—

Cash (paid) refunded during the period for continuing operations—
Interest (net of amounts capitalized)	$	(46,086	)	$	(57,175	)
Income taxes, net	$	(396	)	$	(4,924	)

Employee Benefit Plans

9 Months Ended

Sep. 30, 2014

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]

Pension and Other Postretirement Benefits Disclosure [Text Block]

EMPLOYEE BENEFIT PLANS

Defined Benefit Pension Plans

The components of net periodic benefit cost for the Defined Benefit Pension Plans were as follows (in thousands):



	Three Months Ended September 30,						Nine Months Ended September 30,
	2014			2013			2014			2013
Service cost	$	1,362		$	1,608		$	4,086		$	4,824
Interest cost	3,963			3,825			11,889			11,475
Expected return on plan assets	(4,516		)	(4,654		)	(13,549		)	(13,962		)
Prior service cost	16			16			47			48
Net loss (gain)	1,201			3,062			3,604			9,186
Net periodic benefit cost	$	2,026		$	3,857		$	6,077		$	11,571

Non-pension Defined Benefit Postretirement Healthcare Plans

The components of net periodic benefit cost for the Non-pension Defined Benefit Postretirement Healthcare Plans were as follows (in thousands):



	Three Months Ended September 30,						Nine Months Ended September 30,
	2014			2013			2014			2013
Service cost	$	425		$	419		$	1,275		$	1,257
Interest cost	480			417			1,439			1,251
Expected return on plan assets	(21		)	(20		)	(64		)	(60		)
Prior service cost (benefit)	(107		)	(125		)	(321		)	(375		)
Net loss (gain)	40			121			120			363
Net periodic benefit cost	$	817		$	812		$	2,449		$	2,436

Supplemental Non-qualified Defined Benefit and Defined Contribution Plans

The components of net periodic benefit cost for the Supplemental Non-qualified Defined Benefit and Defined Contribution Plans were as follows (in thousands):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2014		2013		2014		2013
Service cost	$	374	$	348	$	1,123	$	1,044
Interest cost	362		332		1,085		996
Prior service cost	1		1		2		3
Net loss (gain)	124		198		373		594
Net periodic benefit cost	$	861	$	879	$	2,583	$	2,637

Contributions

We made contributions to the benefit plans during 2014 and anticipate that we will make contributions to the benefit plans during 2015. Contributions to the Defined Benefit Pension Plans are cash contributions made directly to the Pension Plan Trust accounts. Contributions to the Healthcare and Supplemental Plan are made in the form of benefit payments. Contributions and anticipated contributions are as follows (in thousands):



	Contributions Made		Contributions Made		Additional Contributions		Contributions
	Three Months Ended September 30, 2014		Nine Months Ended September 30, 2014		Anticipated for 2014		Anticipated for 2015
Defined Benefit Pension Plans	$	10,200	$	10,200	$	—	$	12,500
Non-pension Defined Benefit Postretirement Healthcare Plans	$	956	$	2,868	$	956	$	3,822
Supplemental Non-qualified Defined Benefit and Defined Contribution Plans	$	373	$	1,118	$	373	$	1,494

Commitments and Contingencies

9 Months Ended

Sep. 30, 2014

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies [Text Block]

COMMITMENTS AND CONTINGENCIES

There have been no significant changes to commitments and contingencies from those previously disclosed in Note 18 of our Notes to the Consolidated Financial Statements in our 2013 Annual Report on Form 10-K except for those described below.

Power Purchase Agreement

As disclosed in footnote 16, Black Hills Wyoming sold its CTII 40 MW natural gas-fired generating unit to the City of Gillette, Wyoming on September 3, 2014. Under the terms of the sale, Black Hills Wyoming entered into ancillary agreements, the most significant of which involves a 20-year economy energy PPA. The PPA contains a sharing arrangement where Black Hills Wyoming shares with the City of Gillette savings from wholesale power purchases made on behalf of the City when power costs are less than operating the generating unit. In addition, other ancillary agreements include agreements for Black Hills Wyoming to operate CTII, provide shared facilities, and provide generation dispatch services. Black Hills Wyoming’s previous power sales agreement that sold all of CTII’s output to Cheyenne Light expired on August 31, 2014.

Natural Gas Delivery Agreement

In 2012, we entered into a ten-year gas gathering and processing contract for natural gas production from our properties in the Piceance Basin in Colorado, under which we pay a gathering fee per Mcf. The contract requires us to deliver a minimum of 20,000 Mcf per day. This agreement became effective in first quarter of 2014 upon completion of the processing infrastructure capable of handling the committed volumes.

Reimbursement Agreement

We have a reimbursement agreement in place with Wells Fargo on behalf of Cheyenne Light for the 2009A bonds of $10 million due in 2027 and the 2009B bonds of $7.0 million due in 2021. In the case of default, we hold the assumption of liability for drawings on Cheyenne Light’s Letter of Credit attached to these bonds.

Other Commitments

Construction was completed on Cheyenne Prairie, a 132 MW, $222 million natural gas-fired electric generating facility jointly owned by Cheyenne Light and Black Hills Power. The facility was placed into commercial operation on October 1, 2014. Included in the total cost of Cheyenne Prairie, are contingencies of approximately $2.5 million remaining on contracts pertaining to site finishing, contractor close-outs, and construction management demobilization and cleanup. Resolution of these contingencies is expected in the fourth quarter of 2014.

Oil Creek Fire

On June 29, 2012, a forest and grassland fire occurred in the western Black Hills of Wyoming. A state fire investigator concluded that the fire was caused by the failure of a transmission structure owned, operated and maintained by Black Hills Power. On April 16, 2013, a lawsuit was filed in the United States District Court for the District of Wyoming, which forty-seven plaintiffs and the State of Wyoming have now joined, asserting claims for damages against Black Hills Power. The claims include allegations of negligence, negligence per se, common law nuisance, and trespass. In addition to claims for these compensatory damages, the lawsuit seeks recovery of punitive damages. Our investigation of the cause and origin of the fire is ongoing. We have denied and will vigorously defend all claims arising out of the fire, pending the completion of our investigation. We cannot predict the outcome of our investigation, the viability of alleged claims or the outcome of the litigation.

Civil litigation of this kind, however, is likely to lead to settlement negotiations, including negotiations prompted by pre-trial civil court procedures. We believe such negotiations would effect a settlement of all claims. Regardless of whether the litigation is determined at trial or through settlement, we expect to incur significant investigation, legal and expert services expenses associated with the litigation. We maintain insurance coverage to limit our exposure to losses due to civil liability claims, and related litigation expense. The deductible applicable to some types of claims arising out of this fire is $1.0 million. We expect this coverage to limit our exposure, and we will pursue recoveries to the maximum extent available under the policies. Based upon information currently available, we believe that a loss associated with settlement of pending claims is probable. Accordingly, as of September 30, 2014, we recorded a loss contingency liability related to these claims, and we recorded a receivable for costs we believe are reimbursable and probable of recovery under our insurance coverage. Both of these entries reflect our reasonable estimate of probable future litigation expense and settlement costs; we did not base these contingencies on any determination that it is probable we would be found liable for these claims were they to be litigated.

Given the uncertainty of litigation, however, a loss related to the fire, the litigation and related claims in excess of the loss we have determined to be probable is reasonably possible. However, we cannot reasonably estimate the amount of such possible loss because our investigation and review of damage claims documentation is ongoing, and there are significant factual and legal issues to be resolved. Further claims may be presented by these and other parties. While we have received claims seeking recovery for fire suppression, reclamation and rehabilitation costs, damage to fencing and other personal property, alleged injury to timber, grass or hay, livestock and related operations, and diminished value of real estate, currently totaling $50 million, we are not yet able, for the reasons described above, to reasonably estimate the amount of any reasonable possible losses in excess of the amount we have accrued. Based upon information currently available, however, management does not expect the outcome of the claims to have a material adverse effect upon our consolidated financial condition, results of operations or cash flows.

Dividend Restrictions

Our Revolving Credit Facility and other debt obligations contain restrictions on the payment of cash dividends upon a default or event of default. As of September 30, 2014, we were in compliance with the debt covenants.

Due to our holding company structure, substantially all of our operating cash flows are provided by dividends paid or distributions made by our subsidiaries. The cash to pay dividends to our stockholders is derived from these cash flows. As a result, certain statutory limitations or regulatory or financing agreements could affect the levels of distributions allowed to be made by our subsidiaries. The following restrictions on distributions from our subsidiaries existed at September 30, 2014:


•	Our utilities are generally limited to the amount of dividends allowed to be paid to us as a utility holding company under the Federal Power Act and settlement agreements with state regulatory jurisdictions. As of September 30, 2014, the restricted net assets at our Utilities Group were approximately $73 million.

Guarantees

9 Months Ended

Sep. 30, 2014

Guarantees [Abstract]

Guarantees [Text Block]

GUARANTEES

We have entered into various agreements providing financial or performance assurance to third parties on behalf of certain of our subsidiaries. The agreements include indemnification for reclamation and surety bonds.

We had the following guarantees in place (in thousands):



	Maximum Exposure at
Nature of Guarantee	September 30, 2014		Expiration
Indemnification for subsidiary reclamation/surety bonds ^(a)	$	63,900	Ongoing

_______________________


(a)	We have guarantees in place for reclamation and surety bonds for our subsidiaries. The guarantees were entered into in the normal course of business. To the extent liabilities are incurred as a result of activities covered by the surety bonds, such liabilities are included in our Condensed Consolidated Balance Sheets.

During the second quarter of 2014, guarantees of Black Hills Utility Holdings’ payment obligations up to $70 million arising from commodity transactions for natural gas supply were removed, primarily due to improvement of the corporate credit rating, as well as the conversion of certain guarantees to letters of credit.

Sale of Operating Asset	9 Months Ended
Sale of Operating Asset	Sep. 30, 2014
Sale of Operating Asset [Abstract]
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	SALE OF OPERATING ASSET On September 3, 2014, Black Hills Wyoming closed the sale of its 40 MW CTII natural-gas fired generating unit to the City of Gillette, Wyoming for approximately $22 million, upon expiration on August 31, 2014 of the PPA with Cheyenne Light. Consideration for the sale included ancillary agreements, the most significant of which includes Black Hills Wyoming providing services to the City of Gillette through an economy energy PPA over a term of 20 years. Black Hills Wyoming will recognize a $4.9 million gain on sale over the 20 year term of the agreements. The deferred gain is recorded in Other deferred credits and other liabilities at September 30, 2014 on the accompanying Condensed Consolidated Balance Sheet.

- Definition

The entire disclosure for the facts and circumstances leading to the completed or expected disposal, manner and timing of disposal, the gain (loss) recognized in the income statement and the income statement caption that includes that gain (loss), amounts of revenues and pretax profit or loss reported in discontinued operations, the segment in which the disposal group was reported, and the classification (whether sold or classified as held for sale) and carrying value of the assets and liabilities comprising the disposal group. Includes all disposal groups, including those classified as components of the entity (discontinued operations).

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6360339&loc=d3e1436-107760

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
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+ Details

Subsequent Event	9 Months Ended
Subsequent Event	Sep. 30, 2014
Subsequent Event [Abstract]
Subsequent Events [Text Block]	SUBSEQUENT EVENT Long-Term Debt On October 1, 2014, Black Hills Power and Cheyenne Light sold $160 million of first mortgage bonds in a private placement to provide permanent financing for Cheyenne Prairie. Black Hills Power issued $85 million of 4.43% coupon first mortgage bonds due October 20, 2044, and Cheyenne Light issued $75 million of 4.53% coupon first mortgage bonds due October 20, 2044. Proceeds from Black Hills Power’s bond sale also funded the early redemption of its 5.35% $12 million pollution control revenue bonds, originally due October 1, 2024.

Business Segment Information (Tables)

9 Months Ended

Sep. 30, 2014

Segment Reporting Information, Additional Information [Abstract]

Schedule of Segment Reporting Information [Table Text Block]

Segment information and Corporate activities included in the accompanying Condensed Consolidated Statements of Income (Loss) were as follows (in thousands):



Three Months Ended September 30, 2014	External Operating Revenue		Inter-company Operating Revenue			Net Income (Loss)
Utilities:
Electric	$	171,395	$	3,156		$	18,154
Gas	78,735		—			1,597
Non-regulated Energy:
Power Generation	1,602		20,419			7,829
Coal Mining	6,884		8,689			2,638
Oil and Gas	13,471		—			(3,110		)
Corporate activities	—		—			(272		)
Inter-company eliminations	—		(32,264		)	—
Total	$	272,087	$	—		$	26,836



Three Months Ended September 30, 2013	External Operating Revenue		Inter-company Operating Revenue			Net Income (Loss)
Utilities:
Electric	$	169,401	$	2,003		$	15,097
Gas	67,792		—			(1,450		)
Non-regulated Energy:
Power Generation	1,575		20,393			6,707
Coal Mining	6,713		8,604			2,142
Oil and Gas	14,426		—			(1,682		)
Corporate activities ^(a)	—		—			2,310
Inter-company eliminations	—		(31,000		)	—
Total	$	259,907	$	—		$	23,124



Nine Months Ended September 30, 2014	External Operating Revenues		Intercompany Operating Revenues			Net Income (Loss)
Utilities:
Electric	$	508,230	$	10,307		$	44,156
Gas	440,571		—			28,289
Non-regulated Energy:
Power Generation	4,138		62,211			23,096
Coal Mining	19,085		26,637			7,118
Oil and Gas	43,469		—			(6,792		)
Corporate activities	—		—			(1,093		)
Inter-company eliminations	—		(99,155		)	—
Total	$	1,015,493	$	—		$	94,774



Nine Months Ended September 30, 2013	External Operating Revenues		Intercompany Operating Revenues			Net Income (Loss)
Utilities:
Electric	$	482,222	$	9,844		$	38,063
Gas	373,440		—			20,225
Non-regulated Energy:
Power Generation	3,628		58,825			17,382
Coal Mining	19,530		23,688			5,180
Oil and Gas	41,584		—			(3,699		)
Corporate activities ^(a)	—		—			19,688
Inter-company eliminations	—		(92,357		)	—
Total	$	920,404	$	—		$	96,839

__________


(a)	Corporate activities include a $2.0 million and a $19 million after-tax non-cash mark-to-market gain on certain interest rate swaps for the three and nine months ended September 30, 2013, respectively.

Reconciliation of Assets from Segment to Consolidated [Table Text Block]

Segment information and Corporate balances included in the accompanying Condensed Consolidated Balance Sheets were as follows (in thousands):



Total Assets (net of inter-company eliminations) as of:	September 30, 2014		December 31, 2013		September 30, 2013
Utilities:
Electric ^(a)	$	2,671,601	$	2,525,947	$	2,464,123
Gas	827,069		805,617		757,746
Non-regulated Energy:
Power Generation^(a)	64,359		95,692		102,331
Coal Mining	74,130		78,825		82,155
Oil and Gas	330,781		288,366		264,785
Corporate activities	105,322		80,731		130,100
Total assets	$	4,073,262	$	3,875,178	$	3,801,240

__________


(a)	The PPA under which Black Hills Colorado IPP provides generation to support Colorado Electric customers from the Pueblo Airport Generation Station is accounted for as a capital lease. As such, assets owned by our Power Generation segment are recorded at Colorado Electric under accounting for a capital lease.

Accounts Receivable (Tables)

9 Months Ended

Sep. 30, 2014

Receivables [Abstract]

Schedule of Accounts Receivable [Table Text Block]

Following is a summary of Accounts receivable, net included in the accompanying Condensed Consolidated Balance Sheets (in thousands) as of:



	Accounts		Unbilled		Less Allowance for			Accounts
September 30, 2014	Receivable, Trade		Revenue		Doubtful Accounts			Receivable, net
Electric Utilities	$	53,717	$	21,485	$	(724	)	$	74,478
Gas Utilities	23,409		13,218		(740		)	35,887
Power Generation	1,368		—		—			1,368
Coal Mining	2,563		—		—			2,563
Oil and Gas	7,657		—		(13		)	7,644
Corporate	1,459		—		—			1,459
Total	$	90,173	$	34,703	$	(1,477	)	$	123,399



	Accounts		Unbilled		Less Allowance for			Accounts
December 31, 2013	Receivable, Trade		Revenue		Doubtful Accounts			Receivable, net
Electric Utilities	$	52,437	$	23,823	$	(666	)	$	75,594
Gas Utilities	49,162		41,195		(558		)	89,799
Power Generation	1,722		—		—			1,722
Coal Mining	1,711		—		—			1,711
Oil and Gas	8,156		—		(13		)	8,143
Corporate	604		—		—			604
Total	$	113,792	$	65,018	$	(1,237	)	$	177,573



	Accounts		Unbilled		Less Allowance for			Accounts
September 30, 2013	Receivable, Trade		Revenue		Doubtful Accounts			Receivable, net
Electric Utilities	$	49,254	$	20,153	$	(648	)	$	68,759
Gas Utilities	20,693		11,877		(542		)	32,028
Power Generation	3		—		—			3
Coal Mining	2,677		—		—			2,677
Oil and Gas	8,463		—		(19		)	8,444
Corporate	2,226		—		—			2,226
Total	$	83,316	$	32,030	$	(1,209	)	$	114,137

Regulatory Assets and Liabilities (Tables)

9 Months Ended

Sep. 30, 2014

Regulatory Assets and Liabilities Disclosure [Abstract]

Schedule of Regulatory Assets and Liabilities [Table Text Block]

We had the following regulatory assets and liabilities (in thousands):



	Maximum	As of		As of		As of
	Amortization (in years)	September 30, 2014		December 31, 2013		September 30, 2013
Regulatory assets
Deferred energy and fuel cost adjustments - current^(a)(d)	1	$	26,211	$	16,775	$	17,925
Deferred gas cost adjustments and natural gas price derivatives^(a)(d)	7	49,870		12,366		16,845
AFUDC^(b)	45	12,411		12,315		12,398
Employee benefit plans ^(c)	13	64,908		67,059		114,386
Environmental^(a)	subject to approval	1,314		1,800		1,800
Asset retirement obligations^(a)	44	3,282		3,266		3,262
Bond issue cost^(a)	24	3,311		3,419		3,454
Renewable energy standard adjustment ^(a)	5	12,007		14,186		14,936
Flow through accounting^(c)	35	25,157		20,916		19,222
Other regulatory assets^(a)	15	10,395		10,546		9,099
		$	208,866	$	162,648	$	213,327

Regulatory liabilities
Deferred energy and gas costs^(a)	1	$	5,535	$	11,708	$	14,032
Employee benefit plans^(c)	13	34,409		34,431		60,707
Cost of removal^(a)	44	71,362		64,970		62,069
Other regulatory liabilities^(c)	25	8,378		9,047		9,629
		$	119,684	$	120,156	$	146,437

__________


(a)	Recovery of costs, but we are not allowed a rate of return.


(b)	In addition to recovery of costs, we are allowed a rate of return.


(c)	In addition to recovery or repayment of costs, we are allowed a return on a portion of this amount or a reduction in rate base, respectively.

(d)

Materials, Supplies and Fuel (Tables)

9 Months Ended

Sep. 30, 2014

Inventory, Net [Abstract]

Materials, Supplies and Fuel [Table Text Block]

The following amounts by major classification are included in Materials, supplies and fuel in the accompanying Condensed Consolidated Balance Sheets (in thousands) as of:



	September 30, 2014		December 31, 2013		September 30, 2013
Materials and supplies	$	52,682	$	50,196	$	50,564
Fuel - Electric Utilities	7,108		6,213		6,384
Natural gas in storage held for distribution	45,936		32,069		38,282
Total materials, supplies and fuel	$	105,726	$	88,478	$	95,230

Earnings Per Share (Tables)

9 Months Ended

Sep. 30, 2014

Earnings Per Share [Abstract]

Schedule of Earnings Per Share Reconciliation [Table Text Block]

A reconciliation of share amounts used to compute Earnings (loss) per share in the accompanying Condensed Consolidated Statements of Income (loss) is as follows (in thousands):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2014		2013		2014		2013

Net income (loss) available for common stock	$	26,836	$	23,124	$	94,774	$	96,839

Weighted average shares - basic	44,415		44,201		44,382		44,143
Dilutive effect of:
Equity compensation	193		256		202		252

Weighted average shares - diluted	44,608		44,457		44,584		44,395

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]

The following outstanding securities were not included in the computation of diluted earnings per share as their effect would have been anti-dilutive (in thousands):



	Three Months Ended September 30,		Nine Months Ended September 30,
	2014	2013	2014	2013

Equity compensation	99	—	75	9
Anti-dilutive shares	99	—	75	9

Notes Payable and Current Maturities of Long-term Debt (Tables)

9 Months Ended

Sep. 30, 2014

Debt Disclosure [Abstract]

Schedule of Short-term Debt [Table Text Block]

We had the following short-term debt outstanding in the accompanying Condensed Consolidated Balance Sheets (in thousands) as of:



	September 30, 2014				December 31, 2013				September 30, 2013
	Balance Outstanding		Letters of Credit		Balance Outstanding		Letters of Credit		Balance Outstanding		Letters of Credit
Revolving Credit Facility	$	184,000	$	31,726	$	82,500	$	22,100	$	138,300	$	53,137

Credit Facility and Short Term Debt Covenants [Table Text Block]

Our Revolving Credit Facility and our Term Loan require compliance with the following financial covenant at the end of each quarter:



	As of September 30, 2014	Covenant Requirement
Recourse Leverage Ratio	54%	Less than	65%

Risk Management Activities (Tables)

9 Months Ended

Sep. 30, 2014

Derivative [Line Items]

Schedule of Derivative Instruments [Table Text Block]

The contract or notional amounts, terms of our interest rate swaps and the interest rate swaps balances reflected on the Condensed Consolidated Balance Sheets were as follows (dollars in thousands) as of:



	September 30, 2014			December 31, 2013			September 30, 2013
	Interest Rate Swaps^(a)			Interest Rate Swaps^(a)			Interest Rate Swaps^(b)			De-designated Interest Rate Swaps^(c)
Notional	$	75,000		$	75,000		$	150,000		$	250,000
Weighted average fixed interest rate	4.97		%	4.97		%	5.04		%	5.67		%
Maximum terms in years	2.25			3.00			3.25			0.25
Derivative liabilities, current	$	3,397		$	3,474		$	7,039		$	58,755
Derivative liabilities, non-current	$	3,273		$	5,614		$	11,388		$	—

__________


(a)	These swaps are designated to borrowings on our Revolving Credit Facility, and are priced using three-month LIBOR, matching the floating portion of the related debt.

(b)


(c)	These swaps were settled during the fourth quarter of 2013.

Derivative Instruments, Gain (Loss) [Table Text Block]

The impacts of cash flow hedges on our Condensed Consolidated Statements of Income (Loss) were as follows (in thousands):



Three Months Ended September 30, 2014
Derivatives in Cash Flow Hedging Relationships	Amount of Gain/(Loss) Recognized in AOCI Derivative (Effective Portion)		Location of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	Amount of Reclassified Gain/(Loss) from AOCI into Income (Effective Portion)			Location of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)
Interest rate swaps	$	152	Interest expense	$	(925	)		$	—
Commodity derivatives	4,833		Revenue	(1,135		)		—
Total	$	4,985		$	(2,060	)		$	—



Three Months Ended September 30, 2013
Derivatives in Cash Flow Hedging Relationships	Amount of Gain/(Loss) Recognized in AOCI Derivative (Effective Portion)			Location of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	Amount of Reclassified Gain/(Loss) from AOCI into Income (Effective Portion)			Location of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)
Interest rate swaps	$	(907	)	Interest expense	$	(1,844	)		$	—
Commodity derivatives	(2,140		)	Revenue	(168		)		—
Total	$	(3,047	)		$	(2,012	)		$	—



Nine Months Ended September 30, 2014
Derivatives in Cash Flow Hedging Relationships	Amount of Gain/(Loss) Recognized in AOCI Derivative (Effective Portion)			Location of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	Amount of Reclassified Gain/(Loss) from AOCI into Income (Effective Portion)			Location of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)
Interest rate swaps	$	(277	)	Interest expense	$	(2,745	)		$	—
Commodity derivatives	(1,376		)	Revenue	(2,697		)		—
Total	$	(1,653	)		$	(5,442	)		$	—



Nine Months Ended September 30, 2013
Derivatives in Cash Flow Hedging Relationships	Amount of Gain/(Loss) Recognized in AOCI Derivative (Effective Portion)		Location of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	Amount of Reclassified Gain/(Loss) from AOCI into Income (Effective Portion)			Location of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)
Interest rate swaps	$	141	Interest expense	$	(5,460	)		$	—
Commodity derivatives	86		Revenue	896				—
Total	$	227		$	(4,564	)		$	—

Oil and Gas [Member]

Derivative [Line Items]

Schedule of Derivative Instruments [Table Text Block]



	September 30, 2014				December 31, 2013				September 30, 2013
	Crude Oil Futures, Swaps and Options		Natural Gas Futures and Swaps		Crude Oil Futures, Swaps and Options		Natural Gas Futures and Swaps		Crude Oil Futures, Swaps and Options		Natural Gas Futures and Swaps
Notional ^(a)	391,500		7,930,000		412,500		7,082,500		499,500		9,874,000
Maximum terms in months ^(b)	1		1		3		1		3		1
Derivative assets, current	$	—	$	—	$	55	$	—	$	13	$	113
Derivative assets, non-current	$	—	$	—	$	—	$	—	$	—	$	—
Derivative liabilities, current	$	—	$	—	$	—	$	—	$	98	$	52
Derivative liabilities, non-current	$	—	$	—	$	—	$	—	$	—	$	—

__________


(a)	Crude oil in Bbls, natural gas in MMBtus.


(b)	Refers to the tenor of the derivative instrument. Assets and liabilities are classified as current/non-current based on the production month hedged and the corresponding settlement of the derivative instrument.

Utilities Group [Member]

Derivative [Line Items]

Schedule of Derivative Instruments [Table Text Block]

We had the following derivative balances related to the hedges in our Utilities reflected in our Condensed Consolidated Balance Sheets as of (in thousands):



	September 30, 2014		December 31, 2013		September 30, 2013
Derivative assets, current	$	—	$	662	$	—
Derivative assets, non-current	$	—	$	—	$	—
Derivative liabilities, non-current	$	—	$	—	$	—
Net unrealized (gain) loss included in Regulatory assets or Regulatory liabilities	$	7,470	$	7,567	$	10,652

Contract or Notional Amounts and Terms of Commodity Derivatives[Table Text Block]

The contract or notional amounts and terms of the natural gas derivative commodity instruments held at our Utilities were as follows, as of:



	September 30, 2014		December 31, 2013		September 30, 2013
	Notional (MMBtus)	Maximum Term (months)^(a)	Notional (MMBtus)	Maximum Term (months)^(a)	Notional (MMBtus)	Maximum Term (months)^(a)
Natural gas futures purchased	16,290,000	74	17,930,000	84	14,010,000	74
Natural gas options purchased	7,070,000	6	3,890,000	8	6,810,000	6
Natural gas basis swaps purchased	12,025,000	63	14,785,000	60	9,790,000	63

- Definition

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

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=7476318&loc=d3e41641-113959

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=7476318&loc=SL5624163-113959

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=6886632&loc=d3e76258-113986

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
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Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=7476318&loc=d3e41620-113959

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
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-Section S99
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-Subparagraph (SX 210.4-08.(n)(2))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

+ Details

Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2014

Fair Value Disclosures [Abstract]

Schedule of Fair Value Hierarchy, Measured on Recurring Basis [Table Text Block]



	As of September 30, 2014
	Level 1		Level 2		Level 3		Cash Collateral and Counterparty Netting			Total
	(in thousands)
Assets:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	—	$	—	$	—		$	—
Basis Swaps -- Oil	—		322		—		(322		)	—
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		1,545		—		(1,545		)	—
Commodity derivatives — Utilities	—		4,029		—		(4,029		)	—
Total	$	—	$	5,896	$	—	$	(5,896	)	$	—

Liabilities:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	—	$	—	$	—		$	—
Basis Swaps -- Oil	—		487		—		(487		)	—
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		865		—		(865		)	—
Commodity derivatives — Utilities	—		8,679		—		(8,679		)	—
Interest rate swaps	—		6,670		—		—			6,670
Total	$	—	$	16,701	$	—	$	(10,031	)	$	6,670



	As of December 31, 2013
	Level 1		Level 2		Level 3		Cash Collateral and Counterparty Netting			Total
	(in thousands)
Assets:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	—	$	—	$	—		$	—
Basis Swaps -- Oil	—		130		—		(75		)	55
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		815		—		(815		)	—
Commodity derivatives —Utilities	—		3,030		—		(2,368		)	662
Total	$	—	$	3,975	$	—	$	(3,258	)	$	717

Liabilities:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	—	$	—	$	—		$	—
Basis Swaps -- Oil	—		1,229		—		(1,229		)	—
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		531		—		(531		)	—
Commodity derivatives — Utilities	—		9,100		—		(9,100		)	—
Interest rate swaps	—		9,088		—		—			9,088
Total	$	—	$	19,948	$	—	$	(10,860	)	$	9,088



	As of September 30, 2013
	Level 1		Level 2		Level 3		Cash Collateral and Counterparty Netting			Total
	(in thousands)
Assets:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	2	$	—	$	—		$	2
Basis Swaps -- Oil	—		51		—		(40		)	11
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		1,752		—		(1,639		)	113
Commodity derivatives — Utilities	—		2,351		—		(2,351		)	—
Total	$	—	$	4,156	$	—	$	(4,030	)	$	126

Liabilities:
Commodity derivatives — Oil and Gas
Options -- Oil	$	—	$	142	$	—	$	(77	)	$	65
Basis Swaps -- Oil	—		1,318		—		(1,284		)	34
Options -- Gas	—		—		—		—			—
Basis Swaps -- Gas	—		232		—		(181		)	51
Commodity derivatives — Utilities	—		10,747		—		(10,747		)	—
Interest rate swaps	—		83,142		—		(5,960		)	77,182
Total	$	—	$	95,581	$	—	$	(18,249	)	$	77,332

Schedule of Derivative Instruments Balance Sheet Location [Table Text Block]

The following tables present the fair value and balance sheet classification of our derivative instruments (in thousands):



As of September 30, 2014
	Balance Sheet Location	Fair Value of Asset Derivatives		Fair Value of Liability Derivatives
Derivatives designated as hedges:
Commodity derivatives	Derivative assets — current	$	1,174	$	—
Commodity derivatives	Derivative assets — non-current	692		—
Commodity derivatives	Derivative liabilities — current	—		497
Commodity derivatives	Derivative liabilities — non-current	—		856
Interest rate swaps	Derivative liabilities — current	—		3,397
Interest rate swaps	Derivative liabilities — non-current	—		3,273
Total derivatives designated as hedges		$	1,866	$	8,023

Derivatives not designated as hedges:
Commodity derivatives	Derivative assets — current	$	—	$	—
Commodity derivatives	Derivative assets — non-current	—		—
Commodity derivatives	Derivative liabilities — current	—		48
Commodity derivatives	Derivative liabilities — non-current	—		4,602
Total derivatives not designated as hedges		$	—	$	4,650



As of December 31, 2013
	Balance Sheet Location	Fair Value of Asset Derivatives		Fair Value of Liability Derivatives
Derivatives designated as hedges:
Commodity derivatives	Derivative assets — current	$	248	$	—
Commodity derivatives	Derivative assets — non-current	698		—
Commodity derivatives	Derivative liabilities — current	—		1,541
Commodity derivatives	Derivative liabilities — non-current	—		219
Interest rate swaps	Derivative liabilities — current	—		3,474
Interest rate swaps	Derivative liabilities — non-current	—		5,614
Total derivatives designated as hedges		$	946	$	10,848

Derivatives not designated as hedges:
Commodity derivatives	Derivative assets — current	$	662	$	—
Commodity derivatives	Derivative assets — non-current	—		—
Commodity derivatives	Derivative liabilities — current	—		—
Commodity derivatives	Derivative liabilities — non-current	—		6,732
Total derivatives not designated as hedges		$	662	$	6,732



As of September 30, 2013
	Balance Sheet Location	Fair Value of Asset Derivatives		Fair Value of Liability Derivatives
Derivatives designated as hedges:
Commodity derivatives	Derivative assets — current	$	846	$	—
Commodity derivatives	Derivative assets — non-current	959		—
Commodity derivatives	Derivative liabilities — current	—		1,317
Commodity derivatives	Derivative liabilities — non-current	—		375
Interest rate swaps	Derivative liabilities — current	—		7,039
Interest rate swaps	Derivative liabilities — non-current	—		11,388
Total derivatives designated as hedges		$	1,805	$	20,119

Derivatives not designated as hedges:
Commodity derivatives	Derivative assets — current	$	—	$	—
Commodity derivatives	Derivative assets — non-current	—		—
Commodity derivatives	Derivative liabilities — current	—		1,795
Commodity derivatives	Derivative liabilities — non-current	—		6,601
Interest rate swaps	Derivative liabilities — current	—		64,715
Interest rate swaps	Derivative liabilities — non-current	—		—
Total derivatives not designated as hedges		$	—	$	73,111

Fair Value of Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2014

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments [Table Text Block]

The estimated fair values of our financial instruments, excluding derivatives which are presented in Note 9, were as follows (in thousands) as of:



	September 30, 2014				December 31, 2013				September 30, 2013
	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
Cash and cash equivalents ^(a)	$	11,939	$	11,939	$	7,841	$	7,841	$	13,637	$	13,637
Restricted cash and equivalents ^(a)	$	1,918	$	1,918	$	2	$	2	$	6,782	$	6,782
Notes payable ^(a)	$	184,000	$	184,000	$	82,500	$	82,500	$	138,300	$	138,300
Long-term debt, including current maturities ^(b)	$	1,382,519	$	1,547,359	$	1,396,948	$	1,491,422	$	1,211,673	$	1,325,729

__________


(a)	Carrying value approximates fair value due to either the short-term length of maturity or variable interest rates that approximate prevailing market rates, and therefore is classified in Level 1 in the fair value hierarchy.


(b)	Long-term debt is valued based on observable inputs available either directly or indirectly for similar liabilities in active markets and therefore is classified in Level 2 in the fair value hierarchy.

Other Comprehensive Income (Loss) (Tables)

9 Months Ended

Sep. 30, 2014

Other Comprehensive Income (Loss), Net of Tax [Abstract]

Reclassification Out of Accumulated Other Comprehensive Income (Loss) [Table Text Block]

The components of the reclassification adjustments, net of tax, included in Other Comprehensive Income (Loss) for the periods were as follows (in thousands):



	Location on the Condensed Consolidated Statements of Income (Loss)	Amount Reclassified from AOCI
		Three Months Ended						Nine Months Ended
		September 30, 2014			September 30, 2013			September 30, 2014			September 30, 2013
Gains (losses) on cash flow hedges:
Interest rate swaps	Interest expense	$	925		$	1,844		$	2,745		$	5,460
Commodity contracts	Revenue	1,135			168			2,697			(896		)
		2,060			2,012			5,442			4,564
Income tax	Income tax benefit (expense)	(732		)	(586		)	(1,931		)	(1,469		)
Reclassification adjustments related to cash flow hedges, net of tax		$	1,328		$	1,426		$	3,511		$	3,095

Amortization of defined benefit plans:
Prior service cost	Utilities - Operations and maintenance	$	(26	)	$	(31	)	$	(77	)	$	(93	)
	Non-regulated energy operations and maintenance	(22		)	(32		)	(93		)	(96		)

Actuarial gain (loss)	Utilities - Operations and maintenance	158			425			473			1,267
	Non-regulated energy operations and maintenance	88			275			274			823
		198			637			577			1,901
Income tax	Income tax benefit (expense)	(69		)	(220		)	(202		)	(663		)
Reclassification adjustments related to defined benefit plans, net of tax		$	129		$	417		$	375		$	1,238

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

Balances by classification included within Accumulated other comprehensive income (loss) on the accompanying Condensed Consolidated Balance Sheets are as follows (in thousands):



	Derivatives Designated as Cash Flow Hedges			Employee Benefit Plans			Total
Balance as of December 31, 2012	$	(15,713	)	$	(19,775	)	$	(35,488	)
Other comprehensive income (loss), net of tax	(1,193		)	457			(736		)
Balance as of March 31, 2013	(16,906		)	(19,318		)	(36,224		)
Other comprehensive income (loss), net of tax	5,079			364			5,443
Balance as of June 30, 2013	(11,827		)	(18,954		)	(30,781		)
Other comprehensive income (loss), net of tax	(657		)	417			(240		)
Ending Balance September 30, 2013	$	(12,484	)	$	(18,537	)	$	(31,021	)

Balance as of December 31, 2013	$	(7,133	)	$	(10,289	)	$	(17,422	)
Other comprehensive income (loss), net of tax	(1,478		)	311			(1,167		)
Balance as of March 31, 2014	(8,611		)	(9,978		)	(18,589		)
Other comprehensive income (loss), net of tax	(556		)	(296		)	(852		)
Balance as of June 30, 2014	(9,167		)	(10,274		)	(19,441		)
Other comprehensive income (loss), net of tax	4,473			129			4,602
Ending Balance Sept. 30, 2014	$	(4,694	)	$	(10,145	)	$	(14,839	)

Supplemental Disclosure of Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2014

Supplemental Cash Flow Information [Abstract]

Supplemental Disclosure of Cash Flow Information [Table Text Block]



Nine months ended	September 30, 2014			September 30, 2013
	(in thousands)
Non-cash investing and financing activities from continuing operations—
Property, plant and equipment acquired with accrued liabilities	$	52,484		$	47,214
Increase (decrease) in capitalized assets associated with asset retirement obligations	$	(2,785	)	$	—

Cash (paid) refunded during the period for continuing operations—
Interest (net of amounts capitalized)	$	(46,086	)	$	(57,175	)
Income taxes, net	$	(396	)	$	(4,924	)

Employee Benefit Plans (Tables)

9 Months Ended

Sep. 30, 2014

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]

Schedule of Net Benefit Costs [Table Text Block]

The components of net periodic benefit cost for the Defined Benefit Pension Plans were as follows (in thousands):



	Three Months Ended September 30,						Nine Months Ended September 30,
	2014			2013			2014			2013
Service cost	$	1,362		$	1,608		$	4,086		$	4,824
Interest cost	3,963			3,825			11,889			11,475
Expected return on plan assets	(4,516		)	(4,654		)	(13,549		)	(13,962		)
Prior service cost	16			16			47			48
Net loss (gain)	1,201			3,062			3,604			9,186
Net periodic benefit cost	$	2,026		$	3,857		$	6,077		$	11,571

Non-pension Defined Benefit Postretirement Healthcare Plans

The components of net periodic benefit cost for the Non-pension Defined Benefit Postretirement Healthcare Plans were as follows (in thousands):



	Three Months Ended September 30,						Nine Months Ended September 30,
	2014			2013			2014			2013
Service cost	$	425		$	419		$	1,275		$	1,257
Interest cost	480			417			1,439			1,251
Expected return on plan assets	(21		)	(20		)	(64		)	(60		)
Prior service cost (benefit)	(107		)	(125		)	(321		)	(375		)
Net loss (gain)	40			121			120			363
Net periodic benefit cost	$	817		$	812		$	2,449		$	2,436

Supplemental Non-qualified Defined Benefit and Defined Contribution Plans

The components of net periodic benefit cost for the Supplemental Non-qualified Defined Benefit and Defined Contribution Plans were as follows (in thousands):



	Three Months Ended September 30,				Nine Months Ended September 30,
	2014		2013		2014		2013
Service cost	$	374	$	348	$	1,123	$	1,044
Interest cost	362		332		1,085		996
Prior service cost	1		1		2		3
Net loss (gain)	124		198		373		594
Net periodic benefit cost	$	861	$	879	$	2,583	$	2,637

Schedule of Defined Benefit Plans Contributions [Table Text Block]

Contributions and anticipated contributions are as follows (in thousands):



	Contributions Made		Contributions Made		Additional Contributions		Contributions
	Three Months Ended September 30, 2014		Nine Months Ended September 30, 2014		Anticipated for 2014		Anticipated for 2015
Defined Benefit Pension Plans	$	10,200	$	10,200	$	—	$	12,500
Non-pension Defined Benefit Postretirement Healthcare Plans	$	956	$	2,868	$	956	$	3,822
Supplemental Non-qualified Defined Benefit and Defined Contribution Plans	$	373	$	1,118	$	373	$	1,494

Guarantees (Tables)

9 Months Ended

Sep. 30, 2014

Guarantees [Abstract]

Schedule of Guarantor Obligations [Table Text Block]

We had the following guarantees in place (in thousands):



	Maximum Exposure at
Nature of Guarantee	September 30, 2014		Expiration
Indemnification for subsidiary reclamation/surety bonds ^(a)	$	63,900	Ongoing

_______________________


(a)	We have guarantees in place for reclamation and surety bonds for our subsidiaries. The guarantees were entered into in the normal course of business. To the extent liabilities are incurred as a result of activities covered by the surety bonds, such liabilities are included in our Condensed Consolidated Balance Sheets.

Information Relating to Segment Statement of Income (Details) - USD ($)
$ in Thousands

3 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Segment Reporting Information [Line Items]

Revenue, Net

$ 272,087

$ 259,907

$ 1,015,493

$ 920,404

Net Income (Loss)

26,836

23,124

94,774

96,839

Mark-to-market gain (loss) on certain interest rate swaps, net of tax

2,000

19,000

Inter-company eliminations [Member]

Segment Reporting Information [Line Items]

Revenue, Net

(32,264)

(31,000)

(99,155)

(92,357)

Net Income (Loss)

Corporate activities[Member]

Segment Reporting Information [Line Items]

Revenue, Net

Net Income (Loss)

(272)

2,310

^[1]

(1,093)

19,688

^[1]

Consolidation, Eliminations [Member]

Segment Reporting Information [Line Items]

Revenue, Net

Electric Utilities [Member]

Segment Reporting Information [Line Items]

Revenue, Net

171,395

169,401

508,230

482,222

Net Income (Loss)

18,154

15,097

44,156

38,063

Electric Utilities [Member] | Inter-company eliminations [Member]

Segment Reporting Information [Line Items]

Revenue, Net

3,156

2,003

10,307

9,844

Gas Utilities [Member]

Segment Reporting Information [Line Items]

Revenue, Net

78,735

67,792

440,571

373,440

Net Income (Loss)

1,597

(1,450)

28,289

20,225

Gas Utilities [Member] | Inter-company eliminations [Member]

Segment Reporting Information [Line Items]

Revenue, Net

Power Generation [Member]

Segment Reporting Information [Line Items]

Revenue, Net

1,602

1,575

4,138

3,628

Net Income (Loss)

7,829

6,707

23,096

17,382

Power Generation [Member] | Inter-company eliminations [Member]

Segment Reporting Information [Line Items]

Revenue, Net

20,419

20,393

62,211

58,825

Coal Mining [Member]

Segment Reporting Information [Line Items]

Revenue, Net

6,884

6,713

19,085

19,530

Net Income (Loss)

2,638

2,142

7,118

5,180

Coal Mining [Member] | Inter-company eliminations [Member]

Segment Reporting Information [Line Items]

Revenue, Net

8,689

8,604

26,637

23,688

Oil and Gas [Member]

Segment Reporting Information [Line Items]

Revenue, Net

13,471

14,426

43,469

41,584

Net Income (Loss)

(3,110)

(1,682)

(6,792)

(3,699)

Oil and Gas [Member] | Inter-company eliminations [Member]

Segment Reporting Information [Line Items]

Revenue, Net

$ 0

[1]	Corporate activities include a $2.0 million and a $19 million after-tax non-cash mark-to-market gain on certain interest rate swaps for the three and nine months ended September 30, 2013, respectively.

Segment and Corporate Assets (Details) - USD ($)
$ in Thousands

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Segment Reporting, Asset Reconciling Item [Line Items]

Assets

$ 4,073,262

$ 3,875,178

$ 3,801,240

Corporate activities[Member]

Segment Reporting, Asset Reconciling Item [Line Items]

Assets

105,322

80,731

130,100

Electric Utilities [Member]

Segment Reporting, Asset Reconciling Item [Line Items]

Assets

^[1]

2,671,601

2,525,947

2,464,123

Gas Utilities [Member]

Segment Reporting, Asset Reconciling Item [Line Items]

Assets

827,069

805,617

757,746

Power Generation [Member]

Segment Reporting, Asset Reconciling Item [Line Items]

Assets

^[1]

64,359

95,692

102,331

Coal Mining [Member]

Segment Reporting, Asset Reconciling Item [Line Items]

Assets

74,130

78,825

82,155

Oil and Gas [Member]

Segment Reporting, Asset Reconciling Item [Line Items]

Assets

$ 330,781

$ 288,366

$ 264,785

[1]

The PPA under which Black Hills Colorado IPP provides generation to support Colorado Electric customers from the Pueblo Airport Generation Station is accounted for as a capital lease. As such, assets owned by our Power Generation segment are recorded at Colorado Electric under accounting for a capital lease.

Accounts Receivable (Details) - USD ($) $ in Thousands	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
Accounts Receivable [Line Items]
Allowance for Doubtful Accounts Receivable	$ (1,477)	$ (1,237)	$ (1,209)
Accounts receivable, net	123,399	177,573	114,137
Corporate[Member]
Accounts Receivable [Line Items]
Allowance for Doubtful Accounts Receivable	0	0	0
Accounts receivable, net	1,459	604	2,226
Electric Utilities [Member]
Accounts Receivable [Line Items]
Allowance for Doubtful Accounts Receivable	(724)	(666)	(648)
Accounts receivable, net	74,478	75,594	68,759
Gas Utilities [Member]
Accounts Receivable [Line Items]
Allowance for Doubtful Accounts Receivable	(740)	(558)	(542)
Accounts receivable, net	35,887	89,799	32,028
Power Generation [Member]
Accounts Receivable [Line Items]
Allowance for Doubtful Accounts Receivable	0	0	0
Accounts receivable, net	1,368	1,722	3
Coal Mining [Member]
Accounts Receivable [Line Items]
Allowance for Doubtful Accounts Receivable	0	0	0
Accounts receivable, net	2,563	1,711	2,677
Oil and Gas [Member]
Accounts Receivable [Line Items]
Allowance for Doubtful Accounts Receivable	(13)	(13)	(19)
Accounts receivable, net	7,644	8,143	8,444
Billed Revenues [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	90,173	113,792	83,316
Billed Revenues [Member] \| Corporate[Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	1,459	604	2,226
Billed Revenues [Member] \| Electric Utilities [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	53,717	52,437	49,254
Billed Revenues [Member] \| Gas Utilities [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	23,409	49,162	20,693
Billed Revenues [Member] \| Power Generation [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	1,368	1,722	3
Billed Revenues [Member] \| Coal Mining [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	2,563	1,711	2,677
Billed Revenues [Member] \| Oil and Gas [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	7,657	8,156	8,463
Unbilled Revenues [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	34,703	65,018	32,030
Unbilled Revenues [Member] \| Corporate[Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	0	0	0
Unbilled Revenues [Member] \| Electric Utilities [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	21,485	23,823	20,153
Unbilled Revenues [Member] \| Gas Utilities [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	13,218	41,195	11,877
Unbilled Revenues [Member] \| Power Generation [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	0	0	0
Unbilled Revenues [Member] \| Coal Mining [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	0	0	0
Unbilled Revenues [Member] \| Oil and Gas [Member]
Accounts Receivable [Line Items]
Accounts Receivable, Trade	$ 0	$ 0	$ 0

Regulatory Assets and Liabilities (Details) - USD ($)
$ in Thousands

9 Months Ended

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Assets

$ 208,866

$ 162,648

$ 213,327

Regulatory Liabilities

$ 119,684

120,156

146,437

Deferred energy and gas costs

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Liabilities Amortization Period (in years)

P1Y

Regulatory Liabilities

^[1]

$ 5,535

11,708

14,032

Employee benefit plans

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Liabilities Amortization Period (in years)

P13Y

Regulatory Liabilities

^[2]

$ 34,409

34,431

60,707

Cost of removal

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Liabilities Amortization Period (in years)

P44Y

Regulatory Liabilities

^[1]

$ 71,362

64,970

62,069

Other regulatory liabilities

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Liabilities Amortization Period (in years)

P25Y

Regulatory Liabilities

^[2]

$ 8,378

9,047

9,629

Deferred energy and gas costs

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Assets Amortization Period (in years)

P1Y

Regulatory Assets

^[1],[3]

$ 26,211

16,775

17,925

Deferred gas cost adjustments and natural gas price derivatives

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Assets Amortization Period (in years)

P7Y

Regulatory Assets

^[1],[3]

$ 49,870

12,366

16,845

Allowance for funds used during construction

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Assets Amortization Period (in years)

P45Y

Regulatory Assets

^[4]

$ 12,411

12,315

12,398

Employee benefit plans

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Assets Amortization Period (in years)

P13Y

Regulatory Assets

^[2]

$ 64,908

67,059

114,386

Environmental

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Assets Amortization Period (in years)

subject to approval

Regulatory Assets

^[1]

$ 1,314

1,800

Asset retirement obligations

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Assets Amortization Period (in years)

P44Y

Regulatory Assets

^[1]

$ 3,282

3,266

3,262

Bond issue cost

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Assets Amortization Period (in years)

P24Y

Regulatory Assets

^[1]

$ 3,311

3,419

3,454

Renewable energy standard adjustment

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Assets Amortization Period (in years)

P5Y

Regulatory Assets

^[1]

$ 12,007

14,186

14,936

Flow through accounting

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Assets Amortization Period (in years)

P35Y

Regulatory Assets

^[2]

$ 25,157

20,916

19,222

Other regulatory assets

Schedule Of Regulatory Assets And Liabilities [Line Items]

Regulatory Assets Amortization Period (in years)

P15Y

Regulatory Assets

^[1]

$ 10,395

$ 10,546

$ 9,099

[1]	Recovery of costs, but we are not allowed a rate of return.
[2]	In addition to recovery or repayment of costs, we are allowed a return on a portion of this amount or a reduction in rate base, respectively.
[3]	Our deferred energy, fuel cost, and gas cost adjustments represent the cost of electricity and gas delivered to our electric and gas utility customers that is either higher or lower than current rates and will be recovered or refunded in future rates. Increases in the current year balances as of September 30, 2014 are primarily due to higher natural gas prices driven by demand and market conditions during our peak winter heating season. Our electric and gas utilities file periodic quarterly, semi-annual, and/or annual filings to recover these costs based on the respective cost mechanisms approved by their applicable state utility commissions.
[4]	In addition to recovery of costs, we are allowed a rate of return.

Materials, Supplies and Fuel (Details) - USD ($) $ in Thousands	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
Inventory, Net [Abstract]
Materials and supplies	$ 52,682	$ 50,196	$ 50,564
Fuel - Electric Utilities	7,108	6,213	6,384
Natural gas in storage held for distribution	45,936	32,069	38,282
Total materials, supplies and fuel	$ 105,726	$ 88,478	$ 95,230

Basic to Dilutive EPS (Details) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income (loss) available for common stock	$ 26,836	$ 23,124	$ 94,774	$ 96,839
Weighted average shares - basic	44,415	44,201	44,382	44,143
Dilutive Effect on Basic Earnings Per Share [Abstract]
Equity compensation, shares	193	256	202	252
Weighted average shares - diluted	44,608	44,457	44,584	44,395

Earnings Per Share Anti-dilutive shares (Details) - shares shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Shares	99	0	75	9
Equity compensation [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Shares	99	0	75	9

Notes Payable (Details) - USD ($) $ in Thousands	9 Months Ended
Notes Payable (Details) - USD ($) $ in Thousands	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
Line of Credit Facility [Line Items]
Revolving Credit Facility - Balance Outstanding	$ 184,000	$ 82,500	$ 138,300
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Revolving Credit Facility - Balance Outstanding	184,000	82,500	138,300
Revolving Credit Facility - Letters of Credit Outstanding	31,726	$ 22,100	$ 53,137
Revolving Credit Facility - Current Borrowing Capacity	$ 500,000
Revolving Credit Facility - Expiration Date	May 29, 2019
Revolving Credit Facility - Maximum Borrowing Capacity	$ 750,000
Revolving Credit Facility - Unused Capacity, Commitment Fee Percentage	0.175%
Revolving Credit Facility - Commitment Fee Percentage Decrease	0.025%
Debt Disclosure [Abstract]
Recourse Leverage Ratio	54.00%
Recourse Leverage Ratio, Maximum Allowed, Covenant	65.00%
Revolving Credit Facility [Member] \| Base Rate [Member]
Line of Credit Facility [Line Items]
Revolving Credit Facility - Interest Rate at Period End	0.125%
Debt Instrument Interest Rate Increase Decrease Parenthetical Disclosures [Abstract]
Revolving Credit Facility - Interest Rate Decrease	0.25%
Revolving Credit Facility [Member] \| Eurodollar [Member]
Line of Credit Facility [Line Items]
Revolving Credit Facility - Interest Rate at Period End	1.125%
Debt Instrument Interest Rate Increase Decrease Parenthetical Disclosures [Abstract]
Revolving Credit Facility - Interest Rate Decrease	0.25%
Revolving Credit Facility [Member] \| Letter of Credit [Member]
Line of Credit Facility [Line Items]
Revolving Credit Facility - Interest Rate at Period End	1.125%
Debt Instrument Interest Rate Increase Decrease Parenthetical Disclosures [Abstract]
Revolving Credit Facility - Interest Rate Decrease	0.25%

Current Maturities of Long-Term Debt (Details) - USD ($) $ in Thousands	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 275,000	$ 0	$ 255,694
Black Hills Corporation [Member] \| Corporate Term Loan Due June 2015
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 275,000

Risk Management Activities (Details)
$ in Thousands

9 Months Ended

12 Months Ended

Sep. 30, 2014

USD ($)

bbl

MMBTU

Sep. 30, 2013

USD ($)

bbl

MMBTU

Dec. 31, 2013

USD ($)

bbl

MMBTU

Derivative [Line Items]

Credit Exposure, Non-Investment Grade Company

$ 500

Derivative assets, current

$ 126

$ 717

Derivative assets, non-current

Derivative liabilities, current

3,397

65,944

3,474

Derivative liabilities, non-current

3,273

11,388

5,614

Designated as Hedging Instrument [Member] | Interest Rate Swap [Member]

Derivative [Line Items]

Derivative liabilities, current

3,397

7,039

3,474

Derivative liabilities, non-current

3,273

11,388

5,614

Derivative, Notional Amount

$ 75,000

^[1]

$ 150,000

^[2]

$ 75,000

^[1]

Weighted Average Fixed Interest Rate

4.97%

5.04%

4.97%

Derivative, Remaining Maturity

2 years 3 months

3 years 3 months

3 years

Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net

$ (3,400)

Not Designated as Hedging Instrument [Member] | Interest Rate Swap [Member]

Derivative [Line Items]

Derivative liabilities, current

$ 58,755

Derivative liabilities, non-current

Derivative, Notional Amount

^[3]

$ 250,000

Weighted Average Fixed Interest Rate

5.67%

Derivative, Remaining Maturity

3 months

Oil and Gas [Member]

Derivative [Line Items]

Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months

700

Power Generation [Member] | Designated as Hedging Instrument [Member] | Interest Rate Swap [Member]

Derivative [Line Items]

Derivative, Notional Amount

$ 75,000

Natural Gas, Distribution [Member] | Utilities Group [Member]

Derivative [Line Items]

Derivative assets, current

$ 662

Derivative assets, non-current

Derivative liabilities, non-current

Net Unrealized (Gain) Loss Included in Regulatory assets or Regulatory liabilities

$ 7,470

$ 10,652

$ 7,567

Natural Gas, Distribution [Member] | Utilities Group [Member] | Future [Member] | Purchase Contract [Member]

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount | MMBTU

16,290,000

14,010,000

17,930,000

Derivative, Remaining Maturity

^[4]

74 months

84 months

Natural Gas, Distribution [Member] | Utilities Group [Member] | Commodity Option [Member] | Purchase Contract [Member]

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount | MMBTU

7,070,000

6,810,000

3,890,000

Derivative, Remaining Maturity

^[4]

6 months

8 months

Natural Gas, Distribution [Member] | Utilities Group [Member] | Basis Swap [Member] | Purchase Contract [Member]

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount | MMBTU

12,025,000

9,790,000

14,785,000

Derivative, Remaining Maturity

^[4]

63 months

60 months

Crude Oil [Member] | Oil and Gas [Member] | Swaps and Options [Member]

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount | bbl

^[5]

391,500

499,500

412,500

Maximum terms in months - Hedged in Cash Flow Hedge

^[6]

1 month

3 months

Derivative assets, current

$ 0

$ 13

$ 55

Derivative assets, non-current

Derivative liabilities, current

Derivative liabilities, non-current

$ 0

Natural Gas [Member] | Oil and Gas [Member] | Swap [Member]

Derivative [Line Items]

Derivative, Nonmonetary Notional Amount | MMBTU

^[5]

7,930,000

9,874,000

7,082,500

Maximum terms in months - Hedged in Cash Flow Hedge

^[6]

1 month

Derivative assets, current

$ 0

$ 113

$ 0

Derivative assets, non-current

Derivative liabilities, current

Derivative liabilities, non-current

$ 0

Corporate[Member] | Designated as Hedging Instrument [Member] | Interest Rate Swap [Member]

Derivative [Line Items]

Derivative, Notional Amount

$ 75,000

[1]	These swaps are designated to borrowings on our Revolving Credit Facility, and are priced using three-month LIBOR, matching the floating portion of the related debt.
[2]	At September 30, 2013, $75 million of these interest rate swaps was designated to borrowings on our Revolving Credit Facility and $75 million was designated to borrowings on our project financing debt at Black Hills Wyoming. These swaps were priced using three-month LIBOR, matching the floating portion of the related debt. The portion of the swaps that was designated to Black Hills Wyoming was settled during the fourth quarter of 2013 upon repayment of the Black Hills Wyoming project financing.
[3]	These swaps were settled during the fourth quarter of 2013.
[4]	Term reflects the maximum forward period hedged.
[5]	Crude oil in Bbls, natural gas in MMBtus.
[6]	Refers to the tenor of the derivative instrument. Assets and liabilities are classified as current/non-current based on the production month hedged and the corresponding settlement of the derivative instrument.

Risk Management Activities Hedging Activities (Details) - Cash Flow Hedging [Member] - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain/(Loss) Recognized in AOCI Derivative (Effective Portion)	$ 4,985	$ (3,047)	$ (1,653)	$ 227
Amount of Reclassified Gain/(Loss) from AOCI into Income (Effective Portion)	(2,060)	(2,012)	(5,442)	(4,564)
Amount of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	0	0	0	0
Interest Rate Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain/(Loss) Recognized in AOCI Derivative (Effective Portion)	152	(907)	(277)	141
Amount of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	0	0	0	0
Interest Rate Swap [Member] \| Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Reclassified Gain/(Loss) from AOCI into Income (Effective Portion)	(925)	(1,844)	(2,745)	(5,460)
Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain/(Loss) Recognized in AOCI Derivative (Effective Portion)	4,833	(2,140)	(1,376)	86
Commodity Contract [Member] \| Sales Revenue, Goods, Net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Reclassified Gain/(Loss) from AOCI into Income (Effective Portion)	(1,135)	(168)	(2,697)	896
Amount of Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	$ 0	$ 0	$ 0	$ 0

Fair Value Measurements - Fair Value Hierarchy (Details) - USD ($) $ in Thousands	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
Fair Value, Transfers Between Level 1 and Level 2, Description and Policy [Abstract]
Fair Value, Assets, Level 1 to Level 2 Transfers, Amount	$ 0	$ 0	$ 0
Fair Value, Assets, Level 2 to Level 1 Transfers, Amount	0	0	0
Fair Value, Liabilities, Level 1 to Level 2 Transfers, Amount	0	0	0
Fair Value, Liabilities, Level 2 to Level 1 Transfers, Amount	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure	0	0	0
Liabilities, Fair Value Disclosure	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member] \| Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member] \| Crude Oil [Member] \| Commodity Option [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member] \| Crude Oil [Member] \| Basis Swap [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member] \| Natural Gas [Member] \| Commodity Option [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member] \| Natural Gas [Member] \| Basis Swap [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member] \| Natural Gas, Distribution [Member] \| Utilities Group [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure	5,896	3,975	4,156
Liabilities, Fair Value Disclosure	16,701	19,948	95,581
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member] \| Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities	6,670	9,088	83,142
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member] \| Crude Oil [Member] \| Commodity Option [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	2
Derivative Liabilities	0	0	142
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member] \| Crude Oil [Member] \| Basis Swap [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	322	130	51
Derivative Liabilities	487	1,229	1,318
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member] \| Natural Gas [Member] \| Commodity Option [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member] \| Natural Gas [Member] \| Basis Swap [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	1,545	815	1,752
Derivative Liabilities	865	531	232
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member] \| Natural Gas, Distribution [Member] \| Utilities Group [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	4,029	3,030	2,351
Derivative Liabilities	8,679	9,100	10,747
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure	0	0	0
Liabilities, Fair Value Disclosure	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member] \| Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member] \| Crude Oil [Member] \| Commodity Option [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member] \| Crude Oil [Member] \| Basis Swap [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member] \| Natural Gas [Member] \| Commodity Option [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member] \| Natural Gas [Member] \| Basis Swap [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member] \| Natural Gas, Distribution [Member] \| Utilities Group [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Netting [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure	(5,896)	(3,258)	(4,030)
Liabilities, Fair Value Disclosure	(10,031)	(10,860)	(18,249)
Fair Value, Measurements, Recurring [Member] \| Netting [Member] \| Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities	0	0	(5,960)
Fair Value, Measurements, Recurring [Member] \| Netting [Member] \| Crude Oil [Member] \| Commodity Option [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	(77)
Fair Value, Measurements, Recurring [Member] \| Netting [Member] \| Crude Oil [Member] \| Basis Swap [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	(322)	(75)	(40)
Derivative Liabilities	(487)	(1,229)	(1,284)
Fair Value, Measurements, Recurring [Member] \| Netting [Member] \| Natural Gas [Member] \| Commodity Option [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Netting [Member] \| Natural Gas [Member] \| Basis Swap [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	(1,545)	(815)	(1,639)
Derivative Liabilities	(865)	(531)	(181)
Fair Value, Measurements, Recurring [Member] \| Netting [Member] \| Natural Gas, Distribution [Member] \| Utilities Group [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	(4,029)	(2,368)	(2,351)
Derivative Liabilities	(8,679)	(9,100)	(10,747)
Fair Value, Measurements, Recurring [Member] \| Estimate of Fair Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure	0	717	126
Liabilities, Fair Value Disclosure	6,670	9,088	77,332
Fair Value, Measurements, Recurring [Member] \| Estimate of Fair Value Measurement [Member] \| Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities	6,670	9,088	77,182
Fair Value, Measurements, Recurring [Member] \| Estimate of Fair Value Measurement [Member] \| Crude Oil [Member] \| Commodity Option [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	2
Derivative Liabilities	0	0	65
Fair Value, Measurements, Recurring [Member] \| Estimate of Fair Value Measurement [Member] \| Crude Oil [Member] \| Basis Swap [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	55	11
Derivative Liabilities	0	0	34
Fair Value, Measurements, Recurring [Member] \| Estimate of Fair Value Measurement [Member] \| Natural Gas [Member] \| Commodity Option [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	0
Derivative Liabilities	0	0	0
Fair Value, Measurements, Recurring [Member] \| Estimate of Fair Value Measurement [Member] \| Natural Gas [Member] \| Basis Swap [Member] \| Oil and Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0	113
Derivative Liabilities	0	0	51
Fair Value, Measurements, Recurring [Member] \| Estimate of Fair Value Measurement [Member] \| Natural Gas, Distribution [Member] \| Utilities Group [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	662	0
Derivative Liabilities	$ 0	$ 0	$ 0

Fair Value Measurements - Balance Sheet Location (Details) - USD ($) $ in Thousands	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	$ 1,866	$ 946	$ 1,805
Derivative Liability, Fair Value, Net	8,023	10,848	20,119
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	0	662	0
Derivative Liability, Fair Value, Net	4,650	6,732	73,111
Commodity Contract [Member] \| Designated as Hedging Instrument [Member] \| Derivative Assets, Current [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1,174	248	846
Derivative Asset, Fair Value, Gross Liability	0	0	0
Commodity Contract [Member] \| Designated as Hedging Instrument [Member] \| Derivative Assets, Non-current [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	692	698	959
Derivative Asset, Fair Value, Gross Liability	0	0	0
Commodity Contract [Member] \| Designated as Hedging Instrument [Member] \| Derivative Liabilities, Current [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Asset	0	0	0
Derivative Liability, Fair Value, Gross Liability	497	1,541	1,317
Commodity Contract [Member] \| Designated as Hedging Instrument [Member] \| Derivative Liabilities, Non-current [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Asset	0	0	0
Derivative Liability, Fair Value, Gross Liability	856	219	375
Commodity Contract [Member] \| Not Designated as Hedging Instrument [Member] \| Derivative Assets, Current [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	662	0
Derivative Asset, Fair Value, Gross Liability	0	0	0
Commodity Contract [Member] \| Not Designated as Hedging Instrument [Member] \| Derivative Assets, Non-current [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0	0
Derivative Asset, Fair Value, Gross Liability	0	0	0
Commodity Contract [Member] \| Not Designated as Hedging Instrument [Member] \| Derivative Liabilities, Current [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Asset	0	0	0
Derivative Liability, Fair Value, Gross Liability	48	0	1,795
Commodity Contract [Member] \| Not Designated as Hedging Instrument [Member] \| Derivative Liabilities, Non-current [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Asset	0	0	0
Derivative Liability, Fair Value, Gross Liability	4,602	6,732	6,601
Interest Rate Swap [Member] \| Designated as Hedging Instrument [Member] \| Derivative Liabilities, Current [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Asset	0	0	0
Derivative Liability, Fair Value, Gross Liability	3,397	3,474	7,039
Interest Rate Swap [Member] \| Designated as Hedging Instrument [Member] \| Derivative Liabilities, Non-current [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Asset	0	0	0
Derivative Liability, Fair Value, Gross Liability	$ 3,273	$ 5,614	11,388
Interest Rate Swap [Member] \| Not Designated as Hedging Instrument [Member] \| Derivative Liabilities, Current [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Asset			0
Derivative Liability, Fair Value, Gross Liability			64,715
Interest Rate Swap [Member] \| Not Designated as Hedging Instrument [Member] \| Derivative Liabilities, Non-current [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Asset			0
Derivative Liability, Fair Value, Gross Liability			$ 0

Fair Value of Financial Instruments (Details) - USD ($)
$ in Thousands

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Cash and cash equivalents

$ 11,939

$ 7,841

$ 13,637

Restricted cash and equivalents

1,918

6,782

Notes payable

184,000

82,500

138,300

Carrying Amount [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Cash and cash equivalents

11,939

7,841

13,637

Restricted cash and equivalents

1,918

6,782

Notes payable

184,000

82,500

138,300

Long-term debt, including current maturities

1,382,519

1,396,948

1,211,673

Fair Value [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Cash and cash equivalents, Fair Value

^[1]

11,939

7,841

13,637

Restricted cash and equivalents, Fair Value

^[1]

1,918

6,782

Notes payable, Fair Value

^[1]

184,000

82,500

138,300

Long-term debt, including current maturities, Fair Value

^[2]

$ 1,547,359

$ 1,491,422

$ 1,325,729

[1]	Carrying value approximates fair value due to either the short-term length of maturity or variable interest rates that approximate prevailing market rates, and therefore is classified in Level 1 in the fair value hierarchy.
[2]	Long-term debt is valued based on observable inputs available either directly or indirectly for similar liabilities in active markets and therefore is classified in Level 2 in the fair value hierarchy.

Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense	$ 17,919	$ 23,840	$ 53,665	$ 70,881
Revenue	272,087	259,907	1,015,493	920,404
Utilities - Operating and Maintenance	64,245	66,061	201,546	196,728
Non-regulated energy operations and maintenance	20,170	20,484	63,852	62,703
Income (loss) before earnings (loss) of unconsolidated subsidiaries and income taxes	38,168	36,458	142,124	147,452
Income tax benefit (expense)	(11,332)	(13,334)	(47,349)	(50,527)
Cash Flow Hedging [Member] \| Reclassification Out Of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Income (loss) before earnings (loss) of unconsolidated subsidiaries and income taxes	2,060	2,012	5,442	4,564
Income tax benefit (expense)	(732)	(586)	(1,931)	(1,469)
Net income (loss) available for common stock	1,328	1,426	3,511	3,095
Cash Flow Hedging [Member] \| Reclassification Out Of Accumulated Other Comprehensive Income [Member] \| Interest Rate Contract [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense	925	1,844	2,745	5,460
Cash Flow Hedging [Member] \| Reclassification Out Of Accumulated Other Comprehensive Income [Member] \| Commodity Contract [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Revenue	1,135	168	2,697	(896)
Accumulated Defined Benefit Plans Adjustment, Net Prior Service Cost (Credit) [Member] \| Reclassification Out Of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Utilities - Operating and Maintenance	(26)	(31)	(77)	(93)
Non-regulated energy operations and maintenance	(22)	(32)	(93)	(96)
Accumulated Defined Benefit Plans Adjustment, Net Unamortized Gain (Loss) [Member] \| Reclassification Out Of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Utilities - Operating and Maintenance	158	425	473	1,267
Non-regulated energy operations and maintenance	88	275	274	823
Accumulated Defined Benefit Plans Adjustment [Member] \| Reclassification Out Of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Income (loss) before earnings (loss) of unconsolidated subsidiaries and income taxes	198	637	577	1,901
Income tax benefit (expense)	(69)	(220)	(202)	(663)
Net income (loss) available for common stock	$ 129	$ 417	$ 375	$ 1,238

Accumulated Other Comprehensive Income (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ (14,839)	$ (19,441)	$ (18,589)	$ (31,021)	$ (30,781)	$ (36,224)	$ (14,839)	$ (31,021)	$ (17,422)	$ (35,488)
Other Comprehensive Income (Loss), Net of Tax	4,602	(852)	(1,167)	(240)	5,443	(736)	2,583	4,467
Derivatives Designated as Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax	(4,694)	(9,167)	(8,611)	(12,484)	(11,827)	(16,906)	(4,694)	(12,484)	(7,133)	(15,713)
Other Comprehensive Income (Loss), Net of Tax	4,473	(556)	(1,478)	(657)	5,079	(1,193)
Employee Benefit Plans [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax	(10,145)	(10,274)	(9,978)	(18,537)	(18,954)	(19,318)	$ (10,145)	$ (18,537)	$ (10,289)	$ (19,775)
Other Comprehensive Income (Loss), Net of Tax	$ 129	$ (296)	$ 311	$ 417	$ 364	$ 457

- Definition

Accumulated change in equity from transactions and other events and circumstances from non-owner sources, net of tax effect, at period end. Excludes Net Income (Loss), and accumulated changes in equity from transactions resulting from investments by owners and distributions to owners. Includes foreign currency translation items, certain pension adjustments, unrealized gains and losses on certain investments in debt and equity securities, other than temporary impairment (OTTI) losses related to factors other than credit losses on available-for-sale and held-to-maturity debt securities that an entity does not intend to sell and it is not more likely than not that the entity will be required to sell before recovery of the amortized cost basis, as well as changes in the fair value of derivatives related to the effective portion of a designated cash flow hedge.

+ References + Details

Supplemental Disclosure of Cash Flow Information (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Non-cash Investing and Financing Activities from Continuing Operations [Abstract]
Property, plant and equipment acquired wtih accrued liabilities	$ 52,484	$ 47,214
Increase (decrease) in capitalized assets associated with asset retirement obligations	(2,785)	0
Cash (paid) refunded during the period for continuing operations [Abstract]
Interest (net of amounts capitalized)	(46,086)	(57,175)
Income taxes, net	$ (396)	$ (4,924)

Employee Benefit Plans (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
Employee Benefit Plans (Details) - USD ($) $ in Thousands	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Defined Benefit Pension Plans
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	$ 1,362	$ 1,608	$ 4,086	$ 4,824
Interest cost	3,963	3,825	11,889	11,475
Expected return on plan assets	(4,516)	(4,654)	(13,549)	(13,962)
Prior service cost (benefit)	16	16	47	48
Net loss (gain)	1,201	3,062	3,604	9,186
Net periodic benefit cost	2,026	3,857	6,077	11,571
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions by Employer	10,200		10,200
Estimated Future Employer Contributions in Current Fiscal Year			0
Estimated Future Employer Contributions in Next Fiscal Year			12,500
Non-pension Defined Benefit Postretirement Healthcare Plans
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	425	419	1,275	1,257
Interest cost	480	417	1,439	1,251
Expected return on plan assets	(21)	(20)	(64)	(60)
Prior service cost (benefit)	(107)	(125)	(321)	(375)
Net loss (gain)	40	121	120	363
Net periodic benefit cost	817	812	2,449	2,436
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions by Employer	956		2,868
Estimated Future Employer Contributions in Current Fiscal Year			956
Estimated Future Employer Contributions in Next Fiscal Year			3,822
Supplemental Non-qualified Defined Benefit and Defined Contribution Plans
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	374	348	1,123	1,044
Interest cost	362	332	1,085	996
Prior service cost (benefit)	1	1	2	3
Net loss (gain)	124	198	373	594
Net periodic benefit cost	861	$ 879	2,583	$ 2,637
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions by Employer	$ 373		1,118
Estimated Future Employer Contributions in Current Fiscal Year			373
Estimated Future Employer Contributions in Next Fiscal Year			$ 1,494

Commitments and Contingencies - Reimbursement Agreement (Details) - Electric Utilities [Member] $ in Millions	9 Months Ended
	Sep. 30, 2014 USD ($)
Industrial Development Revenue Bonds Due 2027 [Member]
Debt Instrument, Maturity Date	Mar. 01, 2027
Industrial Development Revenue Bonds Due 2021 [Member]
Debt Instrument, Maturity Date	Sep. 01, 2021
Surety Bond [Member] \| Industrial Development Revenue Bonds Due 2027 [Member]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 10.0
Surety Bond [Member] \| Industrial Development Revenue Bonds Due 2021 [Member]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 7.0

Commitments and Contingencies - Other Commitments (Details) - Cheyenne Prairie [Member] $ in Millions	9 Months Ended
	Sep. 30, 2014 USD ($)
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	$ 222.0
Unrecorded Unconditional Purchase Obligation, Due in Remainder of Fiscal Year	$ 2.5

Commitments and Contingencies - Oil Creek Fire (Details) - Oil Creek Fire [Member] - Loss from Catastrophes [Member] $ in Millions	9 Months Ended
	Sep. 30, 2014 USD ($)
Minimum [Member]
Loss Contingencies [Line Items]
Insurance Coverage Deductible Per Occurrence	$ 1.0
Maximum [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	$ 50.0

Commitments and Contingencies - Dividend Restrictions (Details) $ in Millions	Sep. 30, 2014 USD ($)
Utilities Group [Member]
Related Party Transaction [Line Items]
Restricted Net Assets for Subsidiaries	$ 73

Commitments and Contingencies Commitments and Contingencies - Natural Gas Delivery Agreement (Details)	9 Months Ended
	Sep. 30, 2014 Mcfe
Oil and Gas [Member]
Oil and Gas Delivery Commitments and Contracts, Daily Production	20,000

Guarantees (Details)
$ in Thousands

Sep. 30, 2014

USD ($)

Coal Mining [Member] | Indemnification for subsidiary reclamation/surety bonds

Statement [Line Items]

Guarantor Obligations, Maximum Exposure, Undiscounted

$ 63,900

^[1]

Gas Utilities [Member] | Payment Guarantee [Member]

Statement [Line Items]

Guarantor Obligations, Maximum Exposure, Undiscounted

$ 70,000

[1]

We have guarantees in place for reclamation and surety bonds for our subsidiaries. The guarantees were entered into in the normal course of business. To the extent liabilities are incurred as a result of activities covered by the surety bonds, such liabilities are included in our Condensed Consolidated Balance Sheets.

Sale of Operating Asset (Details) - CTII Natural Gas-Fred Generating Unit [Member] - Power Generation [Member] - USD ($) $ in Millions	Sep. 03, 2014	Sep. 30, 2014
Proceeds from Sale of Property, Plant, and Equipment	$ 22.0
Deferred Gain on Sale of Property		$ 4.9

Subsequent Event (Details) - Electric Utilities [Member] - USD ($) $ in Millions		9 Months Ended
	Oct. 01, 2014	Sep. 30, 2014
Polution Control Revenue Bonds Due 2024 [Member]
Debt Instrument, Interest Rate, Stated Percentage		5.35%
Extinguishment of Debt, Amount		$ 12
Subsequent Event [Member] \| First Mortgage Bonds Due 2044 [Member]
Long-term Debt, Gross	$ 160
Subsequent Event [Member] \| Black Hills Power [Member] \| First Mortgage Bonds Due 2044 [Member]
Long-term Debt, Gross	$ 85
Debt Instrument, Interest Rate, Stated Percentage	4.43%
Debt Instrument, Maturity Date	Oct. 20, 2044
Subsequent Event [Member] \| Cheyenne Light [Member] \| First Mortgage Bonds Due 2044 [Member]
Long-term Debt, Gross	$ 75
Debt Instrument, Interest Rate, Stated Percentage	4.53%
Debt Instrument, Maturity Date	Oct. 20, 2044