10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended March 31, 2017
OR
o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from __________ to __________.
	Commission File Number 1-7978

Black Hills Power, Inc.
Incorporated in South Dakota	IRS Identification Number 46-0111677
625 Ninth Street
Rapid City, South Dakota 57701
Registrant’s telephone number (605) 721-1700
Former name, former address, and former fiscal year if changed since last report
NONE

Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes x No o

Indicate by check mark whether the Registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the Registrant was required to submit and post such files).

Yes x No o

Indicate by check mark whether the Registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	o		Accelerated filer	o
Non-accelerated filer	x	(Do not check if a smaller reporting company)
			Smaller reporting company	o
			Emerging growth company	o

If an emerging growth company, indicate by check mark if the Registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

Indicate by check mark whether the Registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes o No x

As of April 30, 2017, there were issued and outstanding 23,416,396 shares of the Registrant’s common stock, $1.00 par value, all of which were held beneficially and of record by Black Hills Corporation.

Reduced Disclosure

The Registrant meets the conditions set forth in General Instruction H (1) (a) and (b) of Form 10-Q and is therefore filing this Form 10-Q with the reduced disclosure format.

TABLE OF CONTENTS

		Page
	GLOSSARY OF TERMS AND ABBREVIATIONS	3
PART 1.	FINANCIAL INFORMATION
Item 1.	Financial Statements
	Condensed Statements of Income and Comprehensive Income - unaudited	4
	Three Months Ended March 31, 2017 and 2016
	Condensed Balance Sheets - unaudited	5
	March 31, 2017 and December 31, 2016
	Condensed Statements of Cash Flows - unaudited	7
	Three Months Ended March 31, 2017 and 2016
	Notes to Condensed Financial Statements - unaudited	8
Item 2.	Managements’ Discussion and Analysis of Financial Condition and Results of Operations	14
Item 4.	Controls and Procedures	17
PART II.	OTHER INFORMATION	18
Item 1.	Legal Proceedings	18
Item 1A.	Risk Factors	18
Item 6.	Exhibits	18
	Signatures	19
	Exhibit Index	20

2

GLOSSARY OF TERMS AND ABBREVIATIONS

The following terms and abbreviations appear in the text of this report and have the definitions described below:

AFUDC	Allowance for Funds Used During Construction
ASC	Accounting Standards Codification
ASU	Accounting Standards Update issued by the FASB
BHC	Black Hills Corporation; the Parent Company
Black Hills Energy	The name used to conduct the business of BHC utility companies
Black Hills Utility Holdings	Black Hills Utility Holdings, Inc. a direct, wholly-owned subsidiary of Black Hills Corporation (doing business as Black Hills Energy)
Black Hills Service Company	Black Hills Service Company, LLC, a direct, wholly-owned subsidiary of BHC
Cheyenne Light	Cheyenne Light, Fuel and Power Company, a direct, wholly-owned subsidiary of Black Hills Corporation (doing business as Black Hills Energy)
FASB	Financial Accounting Standards Board
FERC	United States Federal Energy Regulatory Commission
Fitch	Fitch Ratings
GAAP	Accounting principles generally accepted in the United States of America
Happy Jack	Happy Jack Wind Farms, LLC, a subsidiary of Duke Energy Generation Services
Heating degree day	A heating degree day is equivalent to each degree that the average of the high and the low temperatures for a day is below 65 degrees. The colder the climate, the greater the number of heating degree days. Heating degree days are used in the utility industry to measure the relative coldness of weather and to compare relative temperatures between one geographic area and another. Normal degree days are based on the National Weather Service data for selected locations over a 30-year average.
kV	Kilovolt
LIBOR	London Interbank Offered Rate
Moody’s	Moody’s Investors Service, Inc.
MW	Megawatts
SEC	U. S. Securities and Exchange Commission
Silver Sage	Silver Sage Windpower, LLC, a subsidiary of Duke Energy Generation Services
S&P	Standard & Poor’s, a division of The McGraw-Hill Companies, Inc.
WRDC	Wyodak Resources Development Corp., an indirect, wholly-owned subsidiary of BHC

3

BLACK HILLS POWER, INC.

CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

	Three Months Ended March 31,
(unaudited)	2017			2016
	(in thousands)
Revenue	$	73,794		$	68,642
Operating expenses:
Fuel and purchased power	23,149			20,730
Operations and maintenance	16,954			17,031
Depreciation and amortization	8,694			8,612
Taxes - property	1,621			1,489
Total operating expenses	50,418			47,862
Operating income	23,376			20,780
Other income (expense):
Interest expense	(6,336		)	(5,454		)
AFUDC - borrowed	192			223
Interest income	707			202
AFUDC - equity	471			423
Other income (expense), net	(53		)	74
Total other income (expense)	(5,019		)	(4,532		)
Income from continuing operations before income taxes	18,357			16,248
Income tax expense	(5,787		)	(5,062		)
Net income	12,570			11,186
Other comprehensive income (loss):
Reclassification adjustments of cash flow hedges settled and included in net income (net of tax (expense) benefit of $(6) and $(6) for the three months ended March 31, 2017 and 2016, respectively)	10			10
Reclassification adjustment of benefit plan liability - net gain (loss) (net of tax (expense) benefit of $(8) and $(7) for the three months ended March 31, 2017 and 2016, respectively)	14			14
Other comprehensive income	24			24
Comprehensive income	$	12,594		$	11,210

The accompanying Notes to Condensed Financial Statements are an integral part of these Condensed Financial Statements.

4

BLACK HILLS POWER, INC.

CONDENSED BALANCE SHEETS

(unaudited)	March 31, 2017			December 31, 2016
	(in thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	1,127		$	234
Receivables - customers, net	27,457			30,614
Receivables - affiliates	5,390			9,526
Other receivables, net	420			351
Money pool notes receivable, net	32,949			28,409
Materials, supplies and fuel	23,244			22,389
Regulatory assets, current	20,536			18,119
Other, current assets	3,286			3,876
Total current assets	114,409			113,518
Investments	4,849			4,841
Property, plant and equipment	1,254,710			1,236,387
Less accumulated depreciation and amortization	(342,400		)	(338,828		)
Total property, plant and equipment, net	912,310			897,559
Other assets:
Regulatory assets, non-current	73,445			74,015
Other, non-current assets	3,545			3,816
Total other assets	76,990			77,831
TOTAL ASSETS	$	1,108,558		$	1,093,749

The accompanying Notes to Condensed Financial Statements are an integral part of these Condensed Financial Statements.

5

BLACK HILLS POWER, INC.

CONDENSED BALANCE SHEETS

(unaudited)	March 31, 2017			December 31, 2016
	(in thousands, except common stock par value and share amounts)
LIABILITIES AND STOCKHOLDER’S EQUITY
Current liabilities:
Accounts payable	$	16,809		$	14,158
Accounts payable - affiliates	27,289			31,799
Accrued liabilities	44,891			37,436
Regulatory liabilities, current	—			84
Total current liabilities	88,989			83,477
Long-term debt	339,791			339,756
Deferred credits and other liabilities:
Deferred income tax liability, net, non-current	214,657			211,443
Regulatory liabilities, non-current	53,896			53,866
Benefit plan liabilities	19,617			19,544
Other, non-current liabilities	1,351			1,001
Total deferred credits and other liabilities	289,521			285,854
Commitments and contingencies (Notes 4, 5 and 8)
Stockholder’s equity:
Common stock $1 par value; 50,000,000 shares authorized; 23,416,396 shares issued	23,416			23,416
Additional paid-in capital	39,575			39,575
Retained earnings	328,504			322,933
Accumulated other comprehensive loss	(1,238		)	(1,262		)
Total stockholder’s equity	390,257			384,662
TOTAL LIABILITIES AND STOCKHOLDER’S EQUITY	$	1,108,558		$	1,093,749

The accompanying Notes to Condensed Financial Statements are an integral part of these Condensed Financial Statements.

6

BLACK HILLS POWER, INC.

CONDENSED STATEMENTS OF CASH FLOWS

(unaudited)	Three Months Ended March 31,
	2017			2016
	(in thousands)
Operating activities:
Net income	$	12,570		$	11,186
Adjustments to reconcile net income to net cash provided by operating activities-
Depreciation and amortization	8,694			8,612
Deferred income tax	2,704			18,076
Employee benefits	205			443
AFUDC - equity	(471		)	(423		)
Other adjustments, net	559			296
Change in operating assets and liabilities -
Accounts receivable and other current assets	7,908			(3,409		)
Accounts payable and other current liabilities	(380		)	(7,656		)
Regulatory assets - current	(2,170		)	(4,193		)
Regulatory liabilities - current	(84		)	—
Other operating activities, net	(152		)	481
Net cash provided by (used in) operating activities	29,383			23,413
Investing activities:
Property, plant and equipment additions	(16,976		)	(18,928		)
Change in money pool notes receivable, net	(11,540		)	13,683
Other investing activities	26			(27		)
Net cash provided by (used in) investing activities	(28,490		)	(5,272		)
Financing activities:
Net cash provided by (used in) financing activities	—			—
Net change in cash and cash equivalents	893			18,141
Cash and cash equivalents, beginning of period	234			297
Cash and cash equivalents, end of period	$	1,127		$	18,438

See Note 7 for supplemental cash flow information.

The accompanying Notes to Condensed Financial Statements are an integral part of these Condensed Financial Statements.

7

BLACK HILLS POWER, INC.

Notes to Condensed Financial Statements

(unaudited)

(Reference is made to Notes to Financial Statements

included in our 2016 Annual Report on Form 10-K)

(1)    MANAGEMENT’S STATEMENT

The unaudited condensed financial statements included herein have been prepared by Black Hills Power, Inc. (the “Company,” “we,” “us,” 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 financial statements should be read in conjunction with the financial statements and the notes thereto, included in our 2016 Annual Report on Form 10-K filed with the SEC.

The information furnished in the accompanying condensed financial statements reflects certain estimates required and all adjustments, including accruals, which are, in the opinion of management, necessary for a fair presentation of the March 31, 2017, December 31, 2016 and March 31, 2016 financial information and are of a normal recurring nature. The results of operations for the three months ended March 31, 2017 and March 31, 2016, and our financial condition as of March 31, 2017 and December 31, 2016 are not necessarily indicative of the results of operations and financial condition to be expected as of or for any other period.

Revisions

Certain revisions have been made to prior years’ financial information to conform to the current year presentation.

We revised our presentation of cash and certain cash transactions processed on behalf of affiliates.  We have banking arrangements at certain financial institutions whereby if required, payments of one account are cleared with cash from other accounts at the same financial institution; therefore, book overdrafts are presented on a combined basis by bank as cash and cash equivalents. Cash collected or disbursed on behalf of affiliates is presented as Receivables - affiliates or Accounts Payable - affiliates. Prior year amounts were corrected to conform to the current year presentation, which decreased cash and cash equivalents by $11 million as of March 31, 2016. It also decreased net cash flows provided by operations by $3.3 million for the three months ended March 31, 2016. We assessed the materiality of these changes, taking into account quantitative and qualitative factors, and determined them to be immaterial to the balance sheet as of March 31, 2016 and to the Statements of Cash Flows for the three months ended March 31, 2016. There is no impact to the Statements of Income or Statements of Comprehensive Income (Loss) for any period reported.

Recently Issued and Adopted Accounting Standards

Compensation - Retirement Benefits: Improving the Presentation of Net Periodic Pension Cost and Net Periodic Post-Retirement Benefit Cost, ASU 2017-07

In March 2017, the FASB issued ASU 2017-07, Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Post-Retirement Benefit Cost”. The changes to the standard require employers to report the service cost component in the same line item(s) as other compensation costs, and require the other components of net periodic pension and post-retirement benefit costs to be separately presented in the income statement outside of income from operations. Additionally, only the service cost component may be eligible for capitalization, when applicable. However, all cost components remain eligible for capitalization under FERC regulations. ASU 2017-07 will be applied retrospectively for the presentation of the service cost component and the other components of net periodic pension and post-retirement benefit costs in the income statement. The capitalization of the service cost component of net period pension and post-retirement benefit costs in assets will be applied on a prospective basis. ASU 2017-07 is effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. We are currently assessing the changes to the standard. The presentation changes required for net periodic pension and post-retirement costs will result in offsetting changes to Operating income and Other income and are not expected to be material.

8

Statement of Cash Flows: Classification of Certain Cash Receipts and Cash Payments, ASU 2016-15

In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the Emerging Issues Task Force). This ASU requires changes in the presentation of certain items including but not limited to debt prepayment or debt extinguishment costs; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance policies and distributions received from equity method investees. The ASU will be effective for fiscal years beginning after December 15, 2017. We will use the retrospective transition method to adopt this standard with fiscal years beginning after December 15, 2017.The adoption of this standard will not have a material impact on our financial position, results of operations or cash flows.

Leases, ASU 2016-02

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which supersedes ASC 840, Leases. This ASU requires lessees to recognize a right-of-use asset and lease liability for all leases with terms of more than 12 months. Lessees are permitted to make an accounting policy election to not recognize the asset and liability for leases with a term of 12 months or less. The ASU does not significantly change the lessees’ recognition, measurement and presentation of expenses and cash flows from the previous accounting standard. Lessors’ accounting under the ASC is largely unchanged from the previous accounting standard. In addition, the ASU expands the disclosure requirements of lease arrangements. Lessees and lessors will use a modified retrospective transition approach, which includes a number of practical expedients. The guidance is effective for us beginning after December 15, 2018. Early adoption is permitted. We are currently assessing the impact that adoption of ASU 2016-02 will have 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. The new disclosure requirements will provide information about the nature, amount, timing and uncertainty of revenue and cash flows from revenue contracts with customers. The guidance is effective for annual and interim reporting periods beginning after December 15, 2017 with early adoption on January 1, 2017 permitted. Entities will have the option of using either a full retrospective or modified retrospective approach to adopting this guidance. Under the modified approach, an entity would recognize the cumulative effect of initially applying the guidance with an adjustment to the opening balance of retained earnings in the period of adoption.

We will adopt this standard for annual and interim reporting periods beginning after December 15, 2017. We continue to actively assess all of our sources of revenue to determine the impact that adoption of the new standard will have on our financial position, results of operations and cash flows. Our evaluation includes identifying revenue streams by like contracts to allow for ease of implementation. A majority of our revenues are from regulated tariff offerings that provide electricity with a defined contractual term. For such arrangements, we expect that the revenue from contracts with the customer will be equivalent to the electricity delivered in that period. Therefore, we do not expect that there will be a significant shift in the timing or pattern of revenue recognition for regulated tariff-based sales. The evaluation of other revenue streams is ongoing, including those tied to longer term contractual commitments. However, a number of industry-specific implementation issues are still unresolved and the final resolution of these issues could impact our current accounting policies and/or patterns for revenue recognition, as well as the transition method selected.

9

(2) ACCOUNTS RECEIVABLE AND ALLOWANCE FOR DOUBTFUL ACCOUNTS

Following is a summary of Receivables - customers, net included in the accompanying Condensed Balance Sheets (in thousands) as of:

	March 31, 2017			December 31, 2016
Accounts receivable trade	$	16,197		$	16,972
Unbilled revenues	11,524			13,799
Allowance for doubtful accounts	(264		)	(157		)
Receivables - customers, net	$	27,457		$	30,614

(3) REGULATORY ACCOUNTING

Our regulated electric operations are subject to regulation by various state and federal agencies. The accounting policies followed are generally subject to the Uniform System of Accounts of the FERC.

Our regulatory assets and liabilities were as follows (in thousands) as of:

	Recovery/Amortization Period (in years)	March 31, 2017		December 31, 2016
Regulatory assets:
Unamortized loss on reacquired debt (a)	8	$	1,745	$	1,815
Deferred taxes on AFUDC (b)	45	9,607		9,367
Employee benefit plans (c)	12	20,100		20,100
Deferred energy and fuel cost adjustments - current (a)	Less than 1 year	23,075		23,016
Deferred taxes on flow through accounting (a)	35	12,802		12,545
Decommissioning costs, net of amortization(b)	8	12,025		12,456
Other regulatory assets (a)(d)	2	14,627		12,835
Total regulatory assets		$	93,981	$	92,134

Regulatory liabilities:
Cost of removal for utility plant (a)	61	$	41,592	$	41,541
Employee benefit plan costs and related deferred taxes (c)	12	12,304		12,304
Other regulatory liabilities	13	—		105
Total regulatory liabilities		$	53,896	$	53,950

____________________

(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) Includes approximately $14 million and $12 million of vegetation management expenses at March 31, 2017 and December 31, 2016, respectively, for which we are allowed a rate of return.

10

(4) RELATED-PARTY TRANSACTIONS

Receivables and Payables

We have accounts receivable and accounts payable balances related to transactions with other BHC subsidiaries. The balances were as follows (in thousands) as of:

	March 31, 2017		December 31, 2016
Receivables - affiliates	$	5,390	$	9,526
Accounts payable - affiliates	$	27,289	$	31,799

Money Pool Notes Receivable and Notes Payable

We have entered into a Utility Money Pool Agreement (the “Agreement”) with BHC, Black Hills Service Company and the utility companies conducting business as Black Hills Energy. We are the administrator of the Money Pool. Under the Agreement, we may borrow from BHC; however the Agreement restricts us from loaning funds to BHC or to any of BHC’s non-utility subsidiaries. The Agreement does not restrict us from paying dividends to BHC. Borrowings and advances under the Agreement bear interest at the weighted average daily cost of our parent company’s external borrowings as defined under the Agreement, or if there are no external funds outstanding on that date, then the rate will be the daily one-month LIBOR plus 1.0%. At March 31, 2017, the average cost of borrowing under the Utility Money Pool was 1.47%.

We had the following balances with the Utility Money Pool (in thousands) as of:

	March 31, 2017		December 31, 2016
Money pool notes receivable, net	$	32,949	$	28,409

Our net interest income (expense) relating to balances with the Utility Money Pool was as follows (in thousands):

	Three Months Ended March 31,
	2017		2016
Net interest income (expense)	$	126	$	278

Other related party activity was as follows (in thousands):

	Three Months Ended March 31,
	2017		2016
Revenue:
Energy sold to Cheyenne Light	$	878	$	661
Rent from electric properties	$	1,272	$	1,213
Fuel and purchased power:
Purchases of coal from WRDC	$	4,280	$	4,796
Purchase of excess energy from Cheyenne Light	$	40	$	55
Purchase of renewable wind energy from Cheyenne Light - Happy Jack	$	606	$	664
Purchase of renewable wind energy from Cheyenne Light - Silver Sage	$	1,019	$	1,127
Gas transportation service agreement:
Gas transportation service agreement with Cheyenne Light for firm and interruptible gas transportation	$	99	$	136
Corporate support:
Corporate support services and fees from Parent, Black Hills Service Company and Black Hills Utility Holdings	$	6,611	$	6,721

11

(5) EMPLOYEE BENEFIT PLANS

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

	Three Months Ended March 31,
	2017			2016
Service cost	$	136		$	151
Interest cost	585			625
Expected return on plan assets	(897		)	(908		)
Prior service cost	11			11
Net loss (gain)	307			499
Net periodic benefit cost	$	142		$	378

Defined Benefit Postretirement Healthcare Plan

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

	Three Months Ended March 31,
	2017			2016
Service cost	$	52		$	51
Interest cost	44			47
Prior service cost (benefit)	(84		)	(84		)
Net periodic benefit cost	$	12		$	14

Supplemental Non-qualified Defined Benefit Plans

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

	Three Months Ended March 31,
	2017		2016
Interest cost	$	29	$	30
Net loss (gain)	22		21
Net periodic benefit cost	$	51	$	51

Contributions

Contributions to the Defined Benefit Pension Plan are cash contributions made directly to the Pension Plan Trust. Contributions to the Healthcare and Supplemental Plans are made in the form of benefit payments. Contributions made for 2017 and anticipated contributions for 2017 and 2018 are as follows (in thousands):

	Contributions Three Months Ended March 31, 2017		Remaining Anticipated Contributions for 2017		Anticipated Contributions for 2018
Defined Benefit Pension Plan	$	—	$	1,305	$	660
Defined Benefit Postretirement Healthcare Plan	$	135	$	406	$	565
Supplemental Non-qualified Defined Benefit Plans	$	62	$	185	$	246

12

(6) FAIR VALUE OF FINANCIAL INSTRUMENTS

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Accounting guidance on fair value measurements establishes a hierarchy for grouping assets and liabilities, based on significance of inputs. For additional information see Note 1 included in our 2016 Annual Report on Form 10-K filed with the SEC.

The estimated fair values of our financial instruments were as follows (in thousands) as of:

	March 31, 2017				December 31, 2016
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Cash and cash equivalents (a)	$	1,127	$	1,127	$	234	$	234
Long-term debt, including current maturities (b)	$	339,791	$	424,453	$	339,756	$	410,466

_________________

(a) Carrying value approximates fair value due to either 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 using the market approach based on observable inputs of quoted market prices and yields available for debt instruments either directly or indirectly for similar maturities and debt ratings in active markets and therefore is classified in Level 2 in the fair value hierarchy. The carrying amount of our variable rate debt approximates fair value due to the variable interest rates with short reset periods.

(7) SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION

Three months ended March 31,	2017			2016
	(in thousands)
Non-cash investing and financing activities -
Property, plant and equipment acquired with accrued liabilities	$	10,998		$	5,087
Non-cash (decrease) to money pool notes receivable, net	$	(7,000	)	$	(12,500	)
Non-cash dividend to Parent	$	7,000		$	12,500
Cash (paid) refunded during the period for -
Interest (net of amounts capitalized)	$	(3,014	)	$	(2,989	)

(8) COMMITMENTS AND CONTINGENCIES

There have been no significant changes to commitments and contingencies from those previously disclosed in Note 11 of our Notes to the Financial Statements in our 2016 Annual Report on Form 10-K.

13

ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND

RESULTS OF OPERATIONS

Amounts are presented on a pre-tax basis unless otherwise indicated.

Minor differences in amounts may result due to rounding.

Significant Events

Regulatory Matters

During the first quarter of 2016, we commenced construction of the $54 million, 230-kV, 144 mile-long transmission line that will connect the Teckla Substation in northeast Wyoming, to the Lange Substation near Rapid City, South Dakota. The first segment of this project connecting Teckla to Osage, WY was energized on August 31, 2016. The second segment of the project is expected to be placed in service in the first half of 2017.

Results of Operations

The following discussion includes financial information prepared in accordance with GAAP, as well as another financial measure, gross margin, that is considered a “non-GAAP financial measure.” Generally, a non-GAAP financial measure is a numerical measure of a company’s financial performance, financial position or cash flows that excludes (or includes) amounts that are included in (or excluded from) the most directly comparable measure calculated and presented in accordance with GAAP. Gross margin (revenue less cost of sales) is a non-GAAP financial measure due to the exclusion of depreciation from the measure. The presentation of gross margin is intended to supplement investors’ understanding of our operating performance.

Gross margin is calculated as operating revenue less cost of fuel and purchased power. Our gross margin is impacted by the fluctuations in power purchases, natural gas and other fuel supply costs. However, while these fluctuating costs impact gross margin as a percentage of revenue, they only impact total gross margin if the costs cannot be passed through to our customers.

Our gross margin measure may not be comparable to other companies’ gross margin measure. Furthermore, this measure is not intended to replace operating income as determined in accordance with GAAP as an indicator of operating performance.

The following tables provide certain financial information and operating statistics:

	Three Months Ended March 31,
	2017			2016			Variance
	(in thousands)
Revenue	$	73,794		$	68,642		$	5,152
Fuel and purchased power	23,149			20,730			2,419
Gross margin	50,645			47,912			2,733
Operating expenses	27,269			27,132			137
Operating income	23,376			20,780			2,596
Interest income (expense), net	(5,437		)	(5,029		)	(408		)
Other income (expense), net	418			497			(79		)
Income tax expense	(5,787		)	(5,062		)	(725		)
Net income	$	12,570		$	11,186		$	1,384

14

Three Months Ended March 31, 2017 Compared to Three Months Ended March 31, 2016. Net income was $13 million compared to $11 million for the same period in the prior year primarily due to the following:

Gross marginincreased primarily due to higher transmission revenue and colder weather as compared to the same period in the prior year.

Operating expenses were comparable to the same period in the prior year.

Interest expense, net was comparable to the same period in the prior year.

Other income, net was comparable to the same period in the prior year.

Income tax expense: The effective tax rate was comparable to the same period in the prior year.

	Electric Revenue by Customer Type
	Three Months Ended March 31,
	(in thousands)
	2017		Percentage Change	2016
Residential	$	20,071	4%	$	19,315
Commercial	24,291		3%	23,589
Industrial	8,454		(1)%	8,501
Municipal	836		1%	831
Total retail revenue	53,652		3%	52,236
Contract wholesale (a)	7,843		88%	4,174
Wholesale off-system (b)	3,833		(16)%	4,586
Other revenue	8,466		11%	7,646
Total revenue	$	73,794	8%	$	68,642

____________________

(a) Increase from the prior year is primarily due to a new power-sales agreement which was effective January 1, 2017.

(b) Decrease in 2017 revenue was primarily driven by commodity prices that impacted power marketing sales.

	Megawatt Hours Sold by Customer Type
	Three Months Ended March 31,
	2017	Percentage Change	2016
Residential	149,572	5%	142,753
Commercial	196,406	4%	188,888
Industrial	109,796	2%	108,021
Municipal	7,605	2%	7,441
Total retail quantity sold	463,379	4%	447,103
Contract wholesale (a)	186,116	193%	63,453
Wholesale off-system (b)	154,496	(20)%	193,373
Total quantity sold	803,991	14%	703,929
Losses and company use	41,841	6%	39,324
Total energy	845,832	14%	743,253

____________________

(a) Effective January 1, 2017, we have an energy sales agreement with Cargill through December 31, 2021 to supply 50 MW of energy during heavy and light load timing intervals.

(b) Decrease in 2017 sales was primarily driven by commodity prices that impacted power marketing sales.

15

	Megawatt Hours Generated and Purchased
	Three Months Ended March 31,
Generated -	2017	Percentage Change	2016
Coal-fired	387,985	—%	388,001
Gas-fired (a)	10,350	(33)%	15,562
Total generated	398,335	(1)%	403,563
Total purchased (b)	447,497	32%	339,690
Total generated and purchased (b)	845,832	14%	743,253

____________________

(a) Decrease is primarily due to the ability to purchase excess generation in the open market at a lower cost than to generate for the three months ended March 31, 2017.

(b) Increase in 2017 is primarily driven by resource needs from a new 50 MW power sales agreement with Cargill, effective January 1, 2017.

	Power Plant Availability
	Three Months Ended March 31,
	2017		2016
Coal-fired plants (a)	89.2	%	92.4	%
Other plants	99.4	%	98.3	%
Total availability	94.6	%	95.8	%

____________________

(a) Decrease is primarily due to a planned outage at Neil Simpson II during the three months ended March 31, 2017.

	Degree Days
	Three Months Ended March 31,
	2017			2016
	Actual	Variance from 30-year Average		Actual	Variance from 30-year Average
Heating degree days	3,130	(3	)%	2,806	(13	)%

Credit Ratings

Credit ratings impact our ability to obtain short and long-term financing, the cost of such financing, and vendor payment terms, including collateral requirements. The following table represents our secured credit rating from each agency’s review which was in effect at March 31, 2017:

Rating Agency	Secured Rating
S&P	A-
Moody’s	A1
Fitch	A

16

FORWARD-LOOKING INFORMATION

This Quarterly Report on Form 10-Q contains forward-looking statements as defined by the SEC. Forward-looking statements are all statements other than statements of historical fact, including without limitation those statements that are identified by the words “anticipates”, “estimates”, “expects”, “intends”, “plans”, “predicts” and similar expressions, and include statements concerning plans, objectives, goals, strategies, future events or performance, and underlying assumptions and other statements that are other than statements of historical facts. From time to time, the Company may publish or otherwise make available forward-looking statements of this nature, including statements contained within Item 2 - Management’s Discussion & Analysis of Financial Condition and Results of Operations.

Forward-looking statements involve risks and uncertainties, which could cause actual results or outcomes to differ materially from those expressed. The Company’s expectations, beliefs and projections are expressed in good faith and are believed by the Company to have a reasonable basis, including without limitation, management’s examination of historical operating trends, data contained in the Company’s records and other data available from third parties. Nonetheless, the Company’s expectations, beliefs or projections may not be achieved or accomplished.

Any forward-looking statement contained in this document speaks only as of the date on which the statement is made, and the Company undertakes no obligation to update any forward-looking statement or statements to reflect events or circumstances that occur after the date on which the statement is made or to reflect the occurrence of unanticipated events. New factors emerge from time to time, and it is not possible for management to predict all of the factors, nor can it assess the effect of each factor on the Company’s business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statement. All forward-looking statements, whether written or oral and whether made by or on behalf of the Company, are expressly qualified by the risk factors and cautionary statements described in Item 1A of our 2016 Annual Report on Form 10-K, including statements contained within Item 1A - Risk Factors and Part II, Item 1A of this Quarterly Report on Form 10-Q.

ITEM 4. CONTROLS AND PROCEDURES

This section should be read in conjunction with Item 9A, “Controls and Procedures” included in our Annual Report on Form 10-K for the year ended December 31, 2016.

Our Chief Executive Officer and Chief Financial Officer evaluated the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934) as of March 31, 2017. Based on their evaluation, they have concluded that our disclosure controls and procedures were effective as of March 31, 2017.

Our disclosure controls and procedures are designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Security Exchange Act of 1934, as amended, is recorded, processed, summarized and reported, within the time periods specified in the Commission’s rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.

Changes in Internal Control over Financial Reporting

During the quarter ended March 31, 2017, there have been no changes in our internal control over financial reporting that have materially affected or are reasonably likely to materially affect our internal control over financial reporting.

17

BLACK HILLS POWER, INC.

Part II - Other Information

Item 1. Legal Proceedings

For information regarding legal proceedings, see Note 11 of Notes to Financial Statements in Item 8 of our 2016 Annual Report on Form 10-K and Note 8 of our Notes to Condensed Financial Statements in this Quarterly Report on Form 10-Q, which information from Note 8 is incorporated by reference into this item.

Item 1A. Risk Factors

There are no material changes to the Risk Factors previously disclosed in Item 1A of Part I in our Annual Report on Form 10-K for the year ended December 31, 2016.

Item 6. Exhibits

Exhibit 3.1* Restated Articles of Incorporation of the Registrant dated March 30, 2015 (filed as Exhibit 3.1 to Registrant’s Form 10-Q for the quarterly period ended March 31, 2015).

Exhibit 3.2* Amended and Restated Bylaws of the Registrant dated March 30, 2015 (filed as Exhibit 3.2 to Registrant’s Form 10-Q for the quarterly period ended March 31, 2015).

Exhibit 4.1* Restated and Amended Indenture of Mortgage and Deed of Trust of Black Hills Corporation (now called Black Hills Power, Inc.) dated as of September 1, 1999 (filed as Exhibit 4.19 to the Registrant’s Post-Effective Amendment No. 1 to the Registrant’s Registration Statement on Form S-3 (No. 333-150669-01)). First Supplemental Indenture, dated as of August 13, 2002, between Black Hills Power, Inc. and The Bank of New York Mellon (as successor to J.P. Morgan Chase Bank), as Trustee (filed as Exhibit 4.20 to the Registrant’s Post-Effective Amendment No. 1 to the Registrant’s Registration Statement on Form S-3 (No. 333-150669-01)). Second Supplemental Indenture, dated as of October 27, 2009, between Black Hills Power, Inc. and The Bank of New York Mellon (filed as Exhibit 4.21 to the Registration Statement on Form S-3 (No. 333-150669-01)). Third Supplemental Indenture, dated as of October 1, 2014, between Black Hills Power, Inc. and The Bank of New York Mellon (filed as Exhibit 10.1 to the Registrant’s Form 8-K filed on October 2, 2014).

Exhibit 31.1 Certification of Chief Executive Officer pursuant to Rule 13a - 14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes - Oxley Act of 2002.

Exhibit 31.2 Certification of Chief Financial Officer pursuant to Rule 13a - 14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes - Oxley Act of 2002.

Exhibit 32.1 Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes - Oxley Act of 2002.

Exhibit 32.2 Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes - Oxley Act of 2002.

Exhibit 101 Financial Statements for XBRL Format

_________________________

* Previously filed as part of the filing indicated and incorporated by reference herein.

18

BLACK HILLS POWER, INC.

Signatures

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

BLACK HILLS POWER, INC.

/S/ DAVID R. EMERY

David R. Emery, Chairman

and Chief Executive Officer

/S/ RICHARD W. KINZLEY

Richard W. Kinzley, Senior Vice President

and Chief Financial Officer

Dated: May 8, 2017

19

EXHIBIT INDEX

Exhibit Number Description

Exhibit 3.1* Restated Articles of Incorporation of the Registrant dated March 30, 2015 (filed as Exhibit 3.1 to Registrant’s Form 10-Q for the quarterly period ended March 31, 2015).

Exhibit 3.2* Amended and Restated Bylaws of the Registrant dated March 30, 2015 (filed as Exhibit 3.2 to Registrant’s Form 10-Q for the quarterly period ended March 31, 2015).

Exhibit 4.1* Restated and Amended Indenture of Mortgage and Deed of Trust of Black Hills Corporation (now called Black Hills Power, Inc.) dated as of September 1, 1999 (filed as Exhibit 4.19 to the Registrant’s Post-Effective Amendment No. 1 to the Registrant’s Registration Statement on Form S-3 (No. 333-150669-01)). First Supplemental Indenture, dated as of August 13, 2002, between Black Hills Power, Inc. and The Bank of New York Mellon (as successor to J.P. Morgan Chase Bank), as Trustee (filed as Exhibit 4.20 to the Registrant’s Post-Effective Amendment No. 1 to the Registrant’s Registration Statement on Form S-3 (No. 333-150669-01)). Second Supplemental Indenture, dated as of October 27, 2009, between Black Hills Power, Inc. and The Bank of New York Mellon (filed as Exhibit 4.21 to the Registration Statement on Form S-3 (No. 333-150669-01)). Third Supplemental Indenture, dated as of October 1, 2014, between Black Hills Power, Inc. and The Bank of New York Mellon (filed as Exhibit 10.1 to the Registrant’s Form 8-K filed on October 2, 2014).

Exhibit 31.1 Certification of Chief Executive Officer pursuant to Rule 13a - 14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes - Oxley Act of 2002.

Exhibit 31.2 Certification of Chief Financial Officer pursuant to Rule 13a - 14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes - Oxley Act of 2002.

Exhibit 32.1 Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes - Oxley Act of 2002.

Exhibit 32.2 Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes - Oxley Act of 2002.

Exhibit 101 Financial Statements for XBRL Format

_________________________

* Previously filed as part of the filing indicated and incorporated by reference herein.

20

EX-31.1

EXHIBIT 31.1

CERTIFICATION

I, David R. Emery, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Black Hills Power, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; and

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; and

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting.

5. The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	May 8, 2017
		/S/ DAVID R. EMERY
		David R. Emery
		Chairman and Chief Executive Officer

EX-31.2

EXHIBIT 31.2

CERTIFICATION

I, Richard W. Kinzley, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Black Hills Power, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting.

5. The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	May 8, 2017
		/S/ RICHARD W. KINZLEY
		Richard W. Kinzley
		Senior Vice President and Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Black Hills Power, Inc. (the “Company”) on Form 10-Q for the period ended March 31, 2017 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, David R. Emery, Chairman and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. ss. 1350, as adopted pursuant to ss. 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13 (a) or

15 (d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material

respects, the financial condition and results of operations of the Company.

Date:	May 8, 2017
		/S/ DAVID R. EMERY
		David R. Emery
		Chairman and Chief Executive Officer

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Black Hills Power, Inc. (the “Company”) on Form 10-Q for the period ended March 31, 2017 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Richard W. Kinzley, Senior Vice President and Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. ss. 1350, as adopted pursuant to ss. 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13 (a) or

15 (d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material

respects, the financial condition and results of operations of the Company.

Date:	May 8, 2017
		/S/ RICHARD W. KINZLEY
		Richard W. Kinzley
		Senior Vice President and Chief Financial Officer

XML

Document and Entity Information Document - shares	3 Months Ended
	Mar. 31, 2017	Apr. 30, 2017
Document Information [Line Items]
Entity Registrant Name	BLACK HILLS POWER INC
Entity Central Index Key	0000012400
Document Type	10-Q
Document Period End Date	Mar. 31, 2017
Amendment Flag	false
Document Fiscal Year End Focus	2017
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		23,416,396

XML

Condensed Statements of Income and Comprehensive Income - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Income Statement [Abstract]
Revenue	$ 73,794	$ 68,642
Operating expenses:
Fuel and purchased power	23,149	20,730
Operations and maintenance	16,954	17,031
Depreciation and amortization	8,694	8,612
Taxes - property	1,621	1,489
Total operating expenses	50,418	47,862
Operating income	23,376	20,780
Other income (expense):
Interest expense	(6,336)	(5,454)
AFUDC - borrowed	192	223
Interest income	707	202
AFUDC - equity	471	423
Other income (expense), net	(53)	74
Total other income (expense)	(5,019)	(4,532)
Income from continuing operations before income taxes	18,357	16,248
Income tax expense	(5,787)	(5,062)
Net income	12,570	11,186
Other comprehensive income (loss):
Reclassification adjustments of cash flow hedges settled and included in net income (net of tax (expense) benefit of $(6) and $(6) for the three months ended March 31, 2017 and 2016, respectively)	10	10
Reclassification adjustment of benefit plan liability - net gain (loss) (net of tax (expense) benefit of $(8) and $(7) for the three months ended March 31, 2017 and 2016, respectively)	14	14
Other comprehensive income	24	24
Comprehensive income	$ 12,594	$ 11,210

XML

Condensed Statements of Income and Comprehensive Income OCI Parenthetical - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Income Statement [Abstract]
Reclassification adjustment of cash flow hedges settled, (tax) benefit	$ (6)	$ (6)
Reclassification adjustment of benefit and other postretirement plans included in net income, (tax) benefit	$ (8)	$ (7)

XML

Condensed Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 1,127	$ 234
Receivables - customers, net	27,457	30,614
Receivables - affiliates	5,390	9,526
Other receivables, net	420	351
Money pool notes receivable, net	32,949	28,409
Materials, supplies and fuel	23,244	22,389
Regulatory assets, current	20,536	18,119
Other, current assets	3,286	3,876
Total current assets	114,409	113,518
Investments	4,849	4,841
Property, plant and equipment	1,254,710	1,236,387
Less accumulated depreciation and amortization	(342,400)	(338,828)
Total property, plant and equipment, net	912,310	897,559
Other assets:
Regulatory assets, non-current	73,445	74,015
Other, non-current assets	3,545	3,816
Total other assets	76,990	77,831
TOTAL ASSETS	1,108,558	1,093,749
Current liabilities:
Accounts payable	16,809	14,158
Accounts payable - affiliates	27,289	31,799
Accrued liabilities	44,891	37,436
Regulatory liabilities, current	0	84
Total current liabilities	88,989	83,477
Long-term debt	339,791	339,756
Deferred credits and other liabilities:
Deferred income tax liability, net, non-current	214,657	211,443
Regulatory liabilities, non-current	53,896	53,866
Benefit plan liabilities	19,617	19,544
Other, non-current liabilities	1,351	1,001
Total deferred credits and other liabilities	289,521	285,854
Commitments and contingencies (Notes 4, 5 and 8)
Stockholder’s equity:
Common stock $1 par value; 50,000,000 shares authorized; 23,416,396 shares issued	23,416	23,416
Additional paid-in capital	39,575	39,575
Retained earnings	328,504	322,933
Accumulated other comprehensive loss	(1,238)	(1,262)
Total stockholder’s equity	390,257	384,662
TOTAL LIABILITIES AND STOCKHOLDER’S EQUITY	$ 1,108,558	$ 1,093,749

XML

Balance Sheet Parentheticals - $ / shares	Mar. 31, 2017	Dec. 31, 2016
Statement of Financial Position [Abstract]
Common Stock, Par Value (usd per share)	$ 1	$ 1
Common Stock, Shares authorized	50,000,000	50,000,000
Common Stock, Shares Issued	23,416,396	23,416,396

XML

Condensed Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Operating activities:
Net income	$ 12,570	$ 11,186
Adjustments to reconcile net income to net cash provided by operating activities-
Depreciation and amortization	8,694	8,612
Deferred income tax	2,704	18,076
Employee benefits	205	443
AFUDC - equity	(471)	(423)
Other adjustments, net	559	296
Change in operating assets and liabilities -
Accounts receivable and other current assets	7,908	(3,409)
Accounts payable and other current liabilities	(380)	(7,656)
Regulatory assets - current	(2,170)	(4,193)
Regulatory liabilities - current	(84)	0
Other operating activities, net	(152)	481
Net cash provided by (used in) operating activities	29,383	23,413
Investing activities:
Property, plant and equipment additions	(16,976)	(18,928)
Change in money pool notes receivable, net	(11,540)	13,683
Other investing activities	26	(27)
Net cash provided by (used in) investing activities	(28,490)	(5,272)
Financing activities:
Net cash provided by (used in) financing activities	0	0
Net change in cash and cash equivalents	893	18,141
Cash and cash equivalents, beginning of period	234	297
Cash and cash equivalents, end of period	$ 1,127	$ 18,438

XML

Management's Statement:

3 Months Ended

Mar. 31, 2017

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Management's Statement

MANAGEMENT’S STATEMENT

The unaudited condensed financial statements included herein have been prepared by Black Hills Power, Inc. (the “Company,” “we,” “us,” 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 financial statements should be read in conjunction with the financial statements and the notes thereto, included in our 2016 Annual Report on Form 10-K filed with the SEC.

The information furnished in the accompanying condensed financial statements reflects certain estimates required and all adjustments, including accruals, which are, in the opinion of management, necessary for a fair presentation of the March 31, 2017, December 31, 2016 and March 31, 2016 financial information and are of a normal recurring nature. The results of operations for the three months ended March 31, 2017 and March 31, 2016, and our financial condition as of March 31, 2017 and December 31, 2016 are not necessarily indicative of the results of operations and financial condition to be expected as of or for any other period.

Revisions

Certain revisions have been made to prior years’ financial information to conform to the current year presentation.

We revised our presentation of cash and certain cash transactions processed on behalf of affiliates.  We have banking arrangements at certain financial institutions whereby if required, payments of one account are cleared with cash from other accounts at the same financial institution; therefore, book overdrafts are presented on a combined basis by bank as cash and cash equivalents. Cash collected or disbursed on behalf of affiliates is presented as Receivables - affiliates or Accounts Payable - affiliates. Prior year amounts were corrected to conform to the current year presentation, which decreased cash and cash equivalents by $11 million as of March 31, 2016. It also decreased net cash flows provided by operations by $3.3 million for the three months ended March 31, 2016. We assessed the materiality of these changes, taking into account quantitative and qualitative factors, and determined them to be immaterial to the balance sheet as of March 31, 2016 and to the Statements of Cash Flows for the three months ended March 31, 2016. There is no impact to the Statements of Income or Statements of Comprehensive Income (Loss) for any period reported.

Recently Issued and Adopted Accounting Standards

Compensation - Retirement Benefits: Improving the Presentation of Net Periodic Pension Cost and Net Periodic Post-Retirement Benefit Cost, ASU 2017-07

In March 2017, the FASB issued ASU 2017-07, Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Post-Retirement Benefit Cost”. The changes to the standard require employers to report the service cost component in the same line item(s) as other compensation costs, and require the other components of net periodic pension and post-retirement benefit costs to be separately presented in the income statement outside of income from operations. Additionally, only the service cost component may be eligible for capitalization, when applicable. However, all cost components remain eligible for capitalization under FERC regulations. ASU 2017-07 will be applied retrospectively for the presentation of the service cost component and the other components of net periodic pension and post-retirement benefit costs in the income statement. The capitalization of the service cost component of net period pension and post-retirement benefit costs in assets will be applied on a prospective basis. ASU 2017-07 is effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. We are currently assessing the changes to the standard. The presentation changes required for net periodic pension and post-retirement costs will result in offsetting changes to Operating income and Other income and are not expected to be material.

Statement of Cash Flows: Classification of Certain Cash Receipts and Cash Payments, ASU 2016-15

In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the Emerging Issues Task Force). This ASU requires changes in the presentation of certain items including but not limited to debt prepayment or debt extinguishment costs; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance policies and distributions received from equity method investees. The ASU will be effective for fiscal years beginning after December 15, 2017. We will use the retrospective transition method to adopt this standard with fiscal years beginning after December 15, 2017.The adoption of this standard will not have a material impact on our financial position, results of operations or cash flows.

Leases, ASU 2016-02

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which supersedes ASC 840, Leases. This ASU requires lessees to recognize a right-of-use asset and lease liability for all leases with terms of more than 12 months. Lessees are permitted to make an accounting policy election to not recognize the asset and liability for leases with a term of 12 months or less. The ASU does not significantly change the lessees’ recognition, measurement and presentation of expenses and cash flows from the previous accounting standard. Lessors’ accounting under the ASC is largely unchanged from the previous accounting standard. In addition, the ASU expands the disclosure requirements of lease arrangements. Lessees and lessors will use a modified retrospective transition approach, which includes a number of practical expedients. The guidance is effective for us beginning after December 15, 2018. Early adoption is permitted. We are currently assessing the impact that adoption of ASU 2016-02 will have 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. The new disclosure requirements will provide information about the nature, amount, timing and uncertainty of revenue and cash flows from revenue contracts with customers. The guidance is effective for annual and interim reporting periods beginning after December 15, 2017 with early adoption on January 1, 2017 permitted. Entities will have the option of using either a full retrospective or modified retrospective approach to adopting this guidance. Under the modified approach, an entity would recognize the cumulative effect of initially applying the guidance with an adjustment to the opening balance of retained earnings in the period of adoption.

We will adopt this standard for annual and interim reporting periods beginning after December 15, 2017. We continue to actively assess all of our sources of revenue to determine the impact that adoption of the new standard will have on our financial position, results of operations and cash flows. Our evaluation includes identifying revenue streams by like contracts to allow for ease of implementation. A majority of our revenues are from regulated tariff offerings that provide electricity with a defined contractual term. For such arrangements, we expect that the revenue from contracts with the customer will be equivalent to the electricity delivered in that period. Therefore, we do not expect that there will be a significant shift in the timing or pattern of revenue recognition for regulated tariff-based sales. The evaluation of other revenue streams is ongoing, including those tied to longer term contractual commitments. However, a number of industry-specific implementation issues are still unresolved and the final resolution of these issues could impact our current accounting policies and/or patterns for revenue recognition, as well as the transition method selected.

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Accounts Receivable and Allowance For Doubtful Accounts:

3 Months Ended

Mar. 31, 2017

Accounts Receivable, Net [Abstract]

Accounts Receivable and Allowance for Doubtful Accounts

ACCOUNTS RECEIVABLE AND ALLOWANCE FOR DOUBTFUL ACCOUNTS

Following is a summary of Receivables - customers, net included in the accompanying Condensed Balance Sheets (in thousands) as of:

	March 31, 2017			December 31, 2016
Accounts receivable trade	$	16,197		$	16,972
Unbilled revenues	11,524			13,799
Allowance for doubtful accounts	(264		)	(157		)
Receivables - customers, net	$	27,457		$	30,614

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Regulatory Accounting:

3 Months Ended

Mar. 31, 2017

Regulated Operations [Abstract]

Regulatory Accounting

REGULATORY ACCOUNTING

Our regulated electric operations are subject to regulation by various state and federal agencies. The accounting policies followed are generally subject to the Uniform System of Accounts of the FERC.

Our regulatory assets and liabilities were as follows (in thousands) as of:

	Recovery/Amortization Period (in years)	March 31, 2017		December 31, 2016
Regulatory assets:
Unamortized loss on reacquired debt (a)	8	$	1,745	$	1,815
Deferred taxes on AFUDC (b)	45	9,607		9,367
Employee benefit plans (c)	12	20,100		20,100
Deferred energy and fuel cost adjustments - current (a)	Less than 1 year	23,075		23,016
Deferred taxes on flow through accounting (a)	35	12,802		12,545
Decommissioning costs, net of amortization(b)	8	12,025		12,456
Other regulatory assets (a)(d)	2	14,627		12,835
Total regulatory assets		$	93,981	$	92,134

Regulatory liabilities:
Cost of removal for utility plant (a)	61	$	41,592	$	41,541
Employee benefit plan costs and related deferred taxes (c)	12	12,304		12,304
Other regulatory liabilities	13	—		105
Total regulatory liabilities		$	53,896	$	53,950

____________________

(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) Includes approximately $14 million and $12 million of vegetation management expenses at March 31, 2017 and December 31, 2016, respectively, for which we are allowed a rate of return.

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Related Party Transactions:

3 Months Ended

Mar. 31, 2017

Related Party Transactions [Abstract]

Related-Party Transactions

RELATED-PARTY TRANSACTIONS

Receivables and Payables

We have accounts receivable and accounts payable balances related to transactions with other BHC subsidiaries. The balances were as follows (in thousands) as of:

	March 31, 2017		December 31, 2016
Receivables - affiliates	$	5,390	$	9,526
Accounts payable - affiliates	$	27,289	$	31,799

Money Pool Notes Receivable and Notes Payable

We have entered into a Utility Money Pool Agreement (the “Agreement”) with BHC, Black Hills Service Company and the utility companies conducting business as Black Hills Energy. We are the administrator of the Money Pool. Under the Agreement, we may borrow from BHC; however the Agreement restricts us from loaning funds to BHC or to any of BHC’s non-utility subsidiaries. The Agreement does not restrict us from paying dividends to BHC. Borrowings and advances under the Agreement bear interest at the weighted average daily cost of our parent company’s external borrowings as defined under the Agreement, or if there are no external funds outstanding on that date, then the rate will be the daily one-month LIBOR plus 1.0%. At March 31, 2017, the average cost of borrowing under the Utility Money Pool was 1.47%.

We had the following balances with the Utility Money Pool (in thousands) as of:

	March 31, 2017		December 31, 2016
Money pool notes receivable, net	$	32,949	$	28,409

Our net interest income (expense) relating to balances with the Utility Money Pool was as follows (in thousands):

	Three Months Ended March 31,
	2017		2016
Net interest income (expense)	$	126	$	278

Other related party activity was as follows (in thousands):

	Three Months Ended March 31,
	2017		2016
Revenue:
Energy sold to Cheyenne Light	$	878	$	661
Rent from electric properties	$	1,272	$	1,213
Fuel and purchased power:
Purchases of coal from WRDC	$	4,280	$	4,796
Purchase of excess energy from Cheyenne Light	$	40	$	55
Purchase of renewable wind energy from Cheyenne Light - Happy Jack	$	606	$	664
Purchase of renewable wind energy from Cheyenne Light - Silver Sage	$	1,019	$	1,127
Gas transportation service agreement:
Gas transportation service agreement with Cheyenne Light for firm and interruptible gas transportation	$	99	$	136
Corporate support:
Corporate support services and fees from Parent, Black Hills Service Company and Black Hills Utility Holdings	$	6,611	$	6,721

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Employee Benefit Plans:

3 Months Ended

Mar. 31, 2017

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

Employee Benefit Plans

EMPLOYEE BENEFIT PLANS

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

	Three Months Ended March 31,
	2017			2016
Service cost	$	136		$	151
Interest cost	585			625
Expected return on plan assets	(897		)	(908		)
Prior service cost	11			11
Net loss (gain)	307			499
Net periodic benefit cost	$	142		$	378

Defined Benefit Postretirement Healthcare Plan

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

	Three Months Ended March 31,
	2017			2016
Service cost	$	52		$	51
Interest cost	44			47
Prior service cost (benefit)	(84		)	(84		)
Net periodic benefit cost	$	12		$	14

Supplemental Non-qualified Defined Benefit Plans

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

	Three Months Ended March 31,
	2017		2016
Interest cost	$	29	$	30
Net loss (gain)	22		21
Net periodic benefit cost	$	51	$	51

Contributions

Contributions to the Defined Benefit Pension Plan are cash contributions made directly to the Pension Plan Trust. Contributions to the Healthcare and Supplemental Plans are made in the form of benefit payments. Contributions made for 2017 and anticipated contributions for 2017 and 2018 are as follows (in thousands):

	Contributions Three Months Ended March 31, 2017		Remaining Anticipated Contributions for 2017		Anticipated Contributions for 2018
Defined Benefit Pension Plan	$	—	$	1,305	$	660
Defined Benefit Postretirement Healthcare Plan	$	135	$	406	$	565
Supplemental Non-qualified Defined Benefit Plans	$	62	$	185	$	246

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Fair Value of Financial Instruments:

3 Months Ended

Mar. 31, 2017

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

FAIR VALUE OF FINANCIAL INSTRUMENTS

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Accounting guidance on fair value measurements establishes a hierarchy for grouping assets and liabilities, based on significance of inputs. For additional information see Note 1 included in our 2016 Annual Report on Form 10-K filed with the SEC.

The estimated fair values of our financial instruments were as follows (in thousands) as of:

	March 31, 2017				December 31, 2016
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Cash and cash equivalents (a)	$	1,127	$	1,127	$	234	$	234
Long-term debt, including current maturities (b)	$	339,791	$	424,453	$	339,756	$	410,466

_________________

(a) Carrying value approximates fair value due to either 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 using the market approach based on observable inputs of quoted market prices and yields available for debt instruments either directly or indirectly for similar maturities and debt ratings in active markets and therefore is classified in Level 2 in the fair value hierarchy. The carrying amount of our variable rate debt approximates fair value due to the variable interest rates with short reset periods.

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Supplemental Disclosure of Cash Flow Information:

3 Months Ended

Mar. 31, 2017

Supplemental Cash Flow Information [Abstract]

Supplemental Disclosure of Cash Flow Information

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION

Three months ended March 31,	2017			2016
	(in thousands)
Non-cash investing and financing activities -
Property, plant and equipment acquired with accrued liabilities	$	10,998		$	5,087
Non-cash (decrease) to money pool notes receivable, net	$	(7,000	)	$	(12,500	)
Non-cash dividend to Parent	$	7,000		$	12,500
Cash (paid) refunded during the period for -
Interest (net of amounts capitalized)	$	(3,014	)	$	(2,989	)

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Commitment and Contingencies:

3 Months Ended

Mar. 31, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

There have been no significant changes to commitments and contingencies from those previously disclosed in Note 11 of our Notes to the Financial Statements in our 2016 Annual Report on Form 10-K.

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Management's Statement: (Policies)

3 Months Ended

Mar. 31, 2017

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Revisions

Revisions

Certain revisions have been made to prior years’ financial information to conform to the current year presentation.

We revised our presentation of cash and certain cash transactions processed on behalf of affiliates.  We have banking arrangements at certain financial institutions whereby if required, payments of one account are cleared with cash from other accounts at the same financial institution; therefore, book overdrafts are presented on a combined basis by bank as cash and cash equivalents. Cash collected or disbursed on behalf of affiliates is presented as Receivables - affiliates or Accounts Payable - affiliates. Prior year amounts were corrected to conform to the current year presentation, which decreased cash and cash equivalents by $11 million as of March 31, 2016. It also decreased net cash flows provided by operations by $3.3 million for the three months ended March 31, 2016. We assessed the materiality of these changes, taking into account quantitative and qualitative factors, and determined them to be immaterial to the balance sheet as of March 31, 2016 and to the Statements of Cash Flows for the three months ended March 31, 2016. There is no impact to the Statements of Income or Statements of Comprehensive Income (Loss) for any period reported.

Recently Issued and Adopted Accounting Standards

Recently Issued and Adopted Accounting Standards

Compensation - Retirement Benefits: Improving the Presentation of Net Periodic Pension Cost and Net Periodic Post-Retirement Benefit Cost, ASU 2017-07

In March 2017, the FASB issued ASU 2017-07, Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Post-Retirement Benefit Cost”. The changes to the standard require employers to report the service cost component in the same line item(s) as other compensation costs, and require the other components of net periodic pension and post-retirement benefit costs to be separately presented in the income statement outside of income from operations. Additionally, only the service cost component may be eligible for capitalization, when applicable. However, all cost components remain eligible for capitalization under FERC regulations. ASU 2017-07 will be applied retrospectively for the presentation of the service cost component and the other components of net periodic pension and post-retirement benefit costs in the income statement. The capitalization of the service cost component of net period pension and post-retirement benefit costs in assets will be applied on a prospective basis. ASU 2017-07 is effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. We are currently assessing the changes to the standard. The presentation changes required for net periodic pension and post-retirement costs will result in offsetting changes to Operating income and Other income and are not expected to be material.

Statement of Cash Flows: Classification of Certain Cash Receipts and Cash Payments, ASU 2016-15

In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the Emerging Issues Task Force). This ASU requires changes in the presentation of certain items including but not limited to debt prepayment or debt extinguishment costs; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance policies and distributions received from equity method investees. The ASU will be effective for fiscal years beginning after December 15, 2017. We will use the retrospective transition method to adopt this standard with fiscal years beginning after December 15, 2017.The adoption of this standard will not have a material impact on our financial position, results of operations or cash flows.

Leases, ASU 2016-02

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which supersedes ASC 840, Leases. This ASU requires lessees to recognize a right-of-use asset and lease liability for all leases with terms of more than 12 months. Lessees are permitted to make an accounting policy election to not recognize the asset and liability for leases with a term of 12 months or less. The ASU does not significantly change the lessees’ recognition, measurement and presentation of expenses and cash flows from the previous accounting standard. Lessors’ accounting under the ASC is largely unchanged from the previous accounting standard. In addition, the ASU expands the disclosure requirements of lease arrangements. Lessees and lessors will use a modified retrospective transition approach, which includes a number of practical expedients. The guidance is effective for us beginning after December 15, 2018. Early adoption is permitted. We are currently assessing the impact that adoption of ASU 2016-02 will have 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. The new disclosure requirements will provide information about the nature, amount, timing and uncertainty of revenue and cash flows from revenue contracts with customers. The guidance is effective for annual and interim reporting periods beginning after December 15, 2017 with early adoption on January 1, 2017 permitted. Entities will have the option of using either a full retrospective or modified retrospective approach to adopting this guidance. Under the modified approach, an entity would recognize the cumulative effect of initially applying the guidance with an adjustment to the opening balance of retained earnings in the period of adoption.

We will adopt this standard for annual and interim reporting periods beginning after December 15, 2017. We continue to actively assess all of our sources of revenue to determine the impact that adoption of the new standard will have on our financial position, results of operations and cash flows. Our evaluation includes identifying revenue streams by like contracts to allow for ease of implementation. A majority of our revenues are from regulated tariff offerings that provide electricity with a defined contractual term. For such arrangements, we expect that the revenue from contracts with the customer will be equivalent to the electricity delivered in that period. Therefore, we do not expect that there will be a significant shift in the timing or pattern of revenue recognition for regulated tariff-based sales. The evaluation of other revenue streams is ongoing, including those tied to longer term contractual commitments. However, a number of industry-specific implementation issues are still unresolved and the final resolution of these issues could impact our current accounting policies and/or patterns for revenue recognition, as well as the transition method selected.

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Accounts Receivable and Allowance For Doubtful Accounts: (Tables)

3 Months Ended

Mar. 31, 2017

Accounts Receivable, Net [Abstract]

Schedule of Accounts Receivable

Following is a summary of Receivables - customers, net included in the accompanying Condensed Balance Sheets (in thousands) as of:

	March 31, 2017			December 31, 2016
Accounts receivable trade	$	16,197		$	16,972
Unbilled revenues	11,524			13,799
Allowance for doubtful accounts	(264		)	(157		)
Receivables - customers, net	$	27,457		$	30,614

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Regulatory Accounting: (Tables)

3 Months Ended

Mar. 31, 2017

Regulated Operations [Abstract]

Schedule of Regulatory Assets

Our regulatory assets and liabilities were as follows (in thousands) as of:

	Recovery/Amortization Period (in years)	March 31, 2017		December 31, 2016
Regulatory assets:
Unamortized loss on reacquired debt (a)	8	$	1,745	$	1,815
Deferred taxes on AFUDC (b)	45	9,607		9,367
Employee benefit plans (c)	12	20,100		20,100
Deferred energy and fuel cost adjustments - current (a)	Less than 1 year	23,075		23,016
Deferred taxes on flow through accounting (a)	35	12,802		12,545
Decommissioning costs, net of amortization(b)	8	12,025		12,456
Other regulatory assets (a)(d)	2	14,627		12,835
Total regulatory assets		$	93,981	$	92,134

Schedule of Regulatory Liabilities

Regulatory liabilities:
Cost of removal for utility plant (a)	61	$	41,592	$	41,541
Employee benefit plan costs and related deferred taxes (c)	12	12,304		12,304
Other regulatory liabilities	13	—		105
Total regulatory liabilities		$	53,896	$	53,950

____________________

(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) Includes approximately $14 million and $12 million of vegetation management expenses at March 31, 2017 and December 31, 2016, respectively, for which we are allowed a rate of return.

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Related Party Transactions: (Tables)

3 Months Ended

Mar. 31, 2017

Related Party Transactions [Abstract]

Schedule of Related Party Accounts Receivable and Payable

The balances were as follows (in thousands) as of:

	March 31, 2017		December 31, 2016
Receivables - affiliates	$	5,390	$	9,526
Accounts payable - affiliates	$	27,289	$	31,799

Schedule of Related Party Notes

We had the following balances with the Utility Money Pool (in thousands) as of:

	March 31, 2017		December 31, 2016
Money pool notes receivable, net	$	32,949	$	28,409

Schedule of Related Party Interest Income Expense

Our net interest income (expense) relating to balances with the Utility Money Pool was as follows (in thousands):

	Three Months Ended March 31,
	2017		2016
Net interest income (expense)	$	126	$	278

Schedule of Revenues and Purchases from Related Parties

Other related party activity was as follows (in thousands):

	Three Months Ended March 31,
	2017		2016
Revenue:
Energy sold to Cheyenne Light	$	878	$	661
Rent from electric properties	$	1,272	$	1,213
Fuel and purchased power:
Purchases of coal from WRDC	$	4,280	$	4,796
Purchase of excess energy from Cheyenne Light	$	40	$	55
Purchase of renewable wind energy from Cheyenne Light - Happy Jack	$	606	$	664
Purchase of renewable wind energy from Cheyenne Light - Silver Sage	$	1,019	$	1,127
Gas transportation service agreement:
Gas transportation service agreement with Cheyenne Light for firm and interruptible gas transportation	$	99	$	136
Corporate support:
Corporate support services and fees from Parent, Black Hills Service Company and Black Hills Utility Holdings	$	6,611	$	6,721

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Employee Benefit Plans: (Tables)

3 Months Ended

Mar. 31, 2017

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

Schedule of Net Benefit Costs

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

	Three Months Ended March 31,
	2017			2016
Service cost	$	136		$	151
Interest cost	585			625
Expected return on plan assets	(897		)	(908		)
Prior service cost	11			11
Net loss (gain)	307			499
Net periodic benefit cost	$	142		$	378

Defined Benefit Postretirement Healthcare Plan

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

	Three Months Ended March 31,
	2017			2016
Service cost	$	52		$	51
Interest cost	44			47
Prior service cost (benefit)	(84		)	(84		)
Net periodic benefit cost	$	12		$	14

Supplemental Non-qualified Defined Benefit Plans

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

	Three Months Ended March 31,
	2017		2016
Interest cost	$	29	$	30
Net loss (gain)	22		21
Net periodic benefit cost	$	51	$	51

Schedule of Defined Benefit Plans Contributions

Contributions made for 2017 and anticipated contributions for 2017 and 2018 are as follows (in thousands):

	Contributions Three Months Ended March 31, 2017		Remaining Anticipated Contributions for 2017		Anticipated Contributions for 2018
Defined Benefit Pension Plan	$	—	$	1,305	$	660
Defined Benefit Postretirement Healthcare Plan	$	135	$	406	$	565
Supplemental Non-qualified Defined Benefit Plans	$	62	$	185	$	246

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Fair Value of Financial Instruments: (Tables)

3 Months Ended

Mar. 31, 2017

Fair Value Disclosures [Abstract]

Schedule of Fair Value of Financial Instruments

The estimated fair values of our financial instruments were as follows (in thousands) as of:

	March 31, 2017				December 31, 2016
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Cash and cash equivalents (a)	$	1,127	$	1,127	$	234	$	234
Long-term debt, including current maturities (b)	$	339,791	$	424,453	$	339,756	$	410,466

_________________

(a) Carrying value approximates fair value due to either 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 using the market approach based on observable inputs of quoted market prices and yields available for debt instruments either directly or indirectly for similar maturities and debt ratings in active markets and therefore is classified in Level 2 in the fair value hierarchy. The carrying amount of our variable rate debt approximates fair value due to the variable interest rates with short reset periods.

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Supplemental Disclosure of Cash Flow Information: (Tables)

3 Months Ended

Mar. 31, 2017

Supplemental Cash Flow Information [Abstract]

Schedule of Cash Flow, Supplemental Disclosures

Three months ended March 31,	2017			2016
	(in thousands)
Non-cash investing and financing activities -
Property, plant and equipment acquired with accrued liabilities	$	10,998		$	5,087
Non-cash (decrease) to money pool notes receivable, net	$	(7,000	)	$	(12,500	)
Non-cash dividend to Parent	$	7,000		$	12,500
Cash (paid) refunded during the period for -
Interest (net of amounts capitalized)	$	(3,014	)	$	(2,989	)

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Management's Statement: Revision (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Prior Period Adjustments Restatement [Line Items]
Net Cash Provided by (Used in) Operating Activities	$ 29,383	$ 23,413
Restatement Adjustment
Prior Period Adjustments Restatement [Line Items]
Net Cash Provided by (Used in) Operating Activities		3,300
Cash and Cash Equivalents
Prior Period Adjustments Restatement [Line Items]
Prior Period Reclassification Adjustment		$ 11,000

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Accounts Receivable and Allowance For Doubtful Accounts: (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Accounts Receivable, Net [Abstract]
Accounts receivable, trade	$ 16,197	$ 16,972
Unbilled Receivables, Current	11,524	13,799
Allowance for doubtful accounts	(264)	(157)
Receivables - customers, net	$ 27,457	$ 30,614

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Regulatory Accounting: Regulatory Assets (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Regulatory Assets [Line Items]
Regulatory Assets	$ 93,981	$ 92,134
Loss on Reacquired Debt
Regulatory Assets [Line Items]
Recovery/Amortization Period (in years)	8 years
Regulatory Assets	$ 1,745	1,815
Allowance For Funds Used During Construction
Regulatory Assets [Line Items]
Recovery/Amortization Period (in years)	45 years
Regulatory Assets	$ 9,607	9,367
Pension and Other Postretirement Plans Costs
Regulatory Assets [Line Items]
Recovery/Amortization Period (in years)	12 years
Regulatory Assets	$ 20,100	20,100
Deferred Fuel Costs
Regulatory Assets [Line Items]
Recovery/Amortization Period (in years)	1 year
Regulatory Assets	$ 23,075	23,016
Flow Through Accounting
Regulatory Assets [Line Items]
Recovery/Amortization Period (in years)	35 years
Regulatory Assets	$ 12,802	12,545
Environmental Restoration Costs
Regulatory Assets [Line Items]
Recovery/Amortization Period (in years)	8 years
Regulatory Assets	$ 12,025	12,456
Other Regulatory Assets
Regulatory Assets [Line Items]
Recovery/Amortization Period (in years)	2 years
Regulatory Assets	$ 14,627	12,835
Vegetation Management
Regulatory Assets [Line Items]
Regulatory Assets	$ 14,000	$ 12,000

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Regulatory Accounting: Regulatory Liabilities (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Regulatory Liabilities [Line Items]
Regulatory Liabilities	$ 53,896	$ 53,950
Cost Of Removal
Regulatory Liabilities [Line Items]
Recovery/Amortization Period (in years)	61 years
Regulatory Liabilities	$ 41,592	41,541
Pension and Other Postretirement Plans Costs
Regulatory Liabilities [Line Items]
Recovery/Amortization Period (in years)	12 years
Regulatory Liabilities	$ 12,304	12,304
Other Regulatory Liabilities
Regulatory Liabilities [Line Items]
Recovery/Amortization Period (in years)	13 years
Regulatory Liabilities	$ 0	$ 105

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Regulatory Accounting: Recovery Period (Details)	3 Months Ended
	Mar. 31, 2017
Deferred Fuel Costs
Regulatory Assets [Line Items]
Regulatory Assets Amortization Period, Unclassified (less than)	1 year

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Related Party Transactions: (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Related Party Transaction [Line Items]
Receivables - affiliates	$ 5,390		$ 9,526
Accounts payable - affiliates	$ 27,289		31,799
Related Party Transaction, Utility Money Pool Interest Rate	1.47%
Money pool notes receivable, net	$ 32,949		$ 28,409
Parent
Related Party Transaction [Line Items]
Commitment fee percentage	1.00%
Utility Money Pool
Related Party Transaction [Line Items]
Net interest income (expense)	$ 126	$ 278
Subsidiary of Common Parent | Corporate support services and fees from Parent, Black Hills Service Company and Black Hills Utility Holdings
Related Party Transaction [Line Items]
Fuel and purchased power	6,611	6,721
Subsidiary of Common Parent | Gas transportation service agreement with Cheyenne Light for firm and interruptible gas transportation
Related Party Transaction [Line Items]
Fuel and purchased power	99	136
Subsidiary of Common Parent | Purchases of coal from WRDC
Related Party Transaction [Line Items]
Fuel and purchased power	4,280	4,796
Subsidiary of Common Parent | Purchase of excess energy from Cheyenne Light
Related Party Transaction [Line Items]
Fuel and purchased power	40	55
Subsidiary of Common Parent | Purchase of renewable wind energy from Cheyenne Light - Happy Jack
Related Party Transaction [Line Items]
Fuel and purchased power	606	664
Subsidiary of Common Parent | Purchase of renewable wind energy from Cheyenne Light - Silver Sage
Related Party Transaction [Line Items]
Fuel and purchased power	1,019	1,127
Subsidiary of Common Parent | Energy sold to Cheyenne Light
Related Party Transaction [Line Items]
Revenue	878	661
Subsidiary of Common Parent | Rent from electric properties
Related Party Transaction [Line Items]
Revenue	$ 1,272	$ 1,213

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Employee Benefit Plans: (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Defined Benefit Pension Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	$ 136	$ 151
Interest cost	585	625
Expected return on plan assets	(897)	(908)
Prior service cost (benefit)	11	11
Net loss (gain)	307	499
Net periodic benefit cost	142	378
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions made by Employer	0
Remaining Anticipated Contributions for Current Year	1,305
Anticipated Contributions for Next Year	660
Defined Benefit Postretirement Healthcare Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	52	51
Interest cost	44	47
Prior service cost (benefit)	(84)	(84)
Net periodic benefit cost	12	14
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions made by Employer	135
Remaining Anticipated Contributions for Current Year	406
Anticipated Contributions for Next Year	565
Supplemental Non-qualified Defined Benefit Plans
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Interest cost	29	30
Net loss (gain)	22	21
Net periodic benefit cost	51	$ 51
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions made by Employer	62
Remaining Anticipated Contributions for Current Year	185
Anticipated Contributions for Next Year	$ 246

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Fair Value of Financial Instruments: (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016	Mar. 31, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents, carrying amount	$ 1,127	$ 234	$ 18,438	$ 297
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents, carrying amount	1,127	234
Long-term debt, including current maturities, carrying amount	339,791	339,756
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents, fair value	1,127	234
Long-term debt, including current maturities, fair value	$ 424,453	$ 410,466

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Supplemental Disclosure of Cash Flow Information: (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Noncash Investing and Financing Items [Abstract]
Property, plant and equipment acquired with accrued liabilities	$ 10,998	$ 5,087
Interest and Income Taxes Paid Net [Abstract]
Interest (net of amounts capitalized)	(3,014)	(2,989)
Subsidiary of Common Parent
Noncash Investing and Financing Items [Abstract]
Non-cash (decrease) to money pool notes receivable, net	(7,000)	(12,500)
Parent
Noncash Investing and Financing Items [Abstract]
Non-cash dividend to Parent	$ 7,000	$ 12,500