UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~March 31,~~September 30, 2023

☐ 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 001-31303

Black Hills Corporation

Incorporated in South Dakota IRS Identification Number 46-0458824

7001 Mount Rushmore Road

Rapid City, South Dakota 57702

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 ☒ No ☐

Indicate by check mark whether the Registrant has submitted electronically every Interactive Data File required to be submitted 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 such files). Yes ☒ No ☐

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.

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 ☐ No ☒

Indicate the number of shares outstanding of each of the issuer’s classes of common stock as of the latest practicable date.


Class	Outstanding at ~~April 28,~~October 31, 2023
Common stock, $1.00 par value	~~66,660,004~~67,991,643	shares

TABLE OF CONTENTS


		Page
Glossary of Terms and Abbreviations		3
Forward-Looking Information		6

PART I. FINANCIAL INFORMATION		7

Item 1.	Financial Statements - unaudited	7
	Consolidated Statements of Income	7
	Consolidated Statements of Comprehensive Income	8
	Consolidated Balance Sheets	9
	Consolidated Statements of Cash Flows	11
	Consolidated Statements of Equity	12
	Condensed Notes to Consolidated Financial Statements	1314
	Note 1. Management’s Statement	1314
	Note 2. Regulatory Matters	14
	Note 3. Commitments, Contingencies and Guarantees	15
	Note 4. Revenue	1516
	Note 5. Financing	1617
	Note 6. Earnings Per Share	1719
	Note 7. Risk Management and Derivatives	1719
	Note 8. Fair Value Measurements	2022
	Note 9. Other Comprehensive Income	2224
	Note 10. Employee Benefit Plans	2325
	Note 11. Income Taxes	2326
	Note 12. Business Segment Information	2426
	Note 13. Selected Balance Sheet Information	2527
	Note 14. Subsequent Events	2527

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	2628
	Executive Summary	2628
	Recent Developments	2628
	Results of Operations	2629
	Consolidated Summary and Overview	2729
	Non-GAAP Financial Measure	2730
	Electric Utilities	2830
	Gas Utilities	3034
	Corporate and Other	3135
	Consolidated Interest Expense, Other Income and Income Tax Expense	3236
	Liquidity and Capital Resources	3337
	Cash Flow Activities	3337
	Capital Resources	3438
	Credit Ratings	3539
	Capital Requirements	3539
	Critical Accounting Estimates	3540
	New Accounting Pronouncements	3640

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3640
Item 4.	Controls and Procedures	3640

PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	3640
Item 1A.	Risk Factors	3640
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3640
Item 4.	Mine Safety Disclosures	3641
Item 5.	Other Information	41
Item 6.	Exhibits	3741

Signatures		3842

Table of Contents

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
AOCI	Accumulated Other Comprehensive Income (Loss)
Arkansas Gas	Black Hills Energy Arkansas, Inc., an indirect, wholly-owned subsidiary of Black Hills Utility Holdings, providing natural gas services to customers in Arkansas (doing business as Black Hills Energy).
~~ASU~~	~~Accounting Standards Update issued by the FASB~~
ATM	At-the-market equity offering program
Availability	The availability factor of a power plant is the percentage of the time that it is available to provide energy.
BHC	Black Hills Corporation; the Company
Black Hills Colorado IPP	Black Hills Colorado IPP, LLC a 50.1% owned subsidiary of Black Hills Electric Generation
Black Hills Electric Generation	Black Hills Electric Generation, LLC, a direct, wholly-owned subsidiary of Black Hills Non-regulated Holdings, providing wholesale electric capacity and energy primarily to our affiliate utilities.
Black Hills Electric Parent Holdings	Black Hills Electric Utility Holdings, LLC., a direct, wholly-owned subsidiary of Black Hills Corporation
Black Hills Energy	The name used to conduct the business of our utility ~~companies.~~companies
Black Hills Energy Services	Black Hills Energy Services Company, an indirect, wholly-owned subsidiary of Black Hills Utility Holdings, providing natural gas commodity supply for the Choice Gas Programs (doing business as Black Hills Energy)
Black Hills Non-regulated Holdings	Black Hills Non-regulated Holdings, LLC, a direct, wholly-owned subsidiary of Black Hills Corporation
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 Wyoming	Black Hills Wyoming, LLC, a direct, wholly-owned subsidiary of Black Hills Electric Generation
~~Blockchain Interruptible Service (BCIS) tariff~~	The BCIS tariff was proposed by Wyoming Electric and approved by the WPSC in 2019. The tariff was developed to attract new large electric loads related to blockchain and other industry growth with high energy demand.
~~Cheyenne Light~~	~~Cheyenne Light, Fuel and Power Company, a direct, wholly-owned subsidiary of Black Hills Corporation, providing electric service in the Cheyenne, Wyoming area (doing business as Black Hills Energy).~~
Choice Gas Program	Regulator-approved programs in Wyoming and Nebraska that allow certain utility customers to select their natural gas commodity supplier, providing for the unbundling of the commodity service from the distribution delivery service.
Clean Energy Plan	2030 Ready Plan that establishes a roadmap and preferred resource portfolio for Colorado Electric to cost-effectively achieve the State of Colorado's requirement calling upon electric utilities to reduce GHG emissions by a minimum of 80% from 2005 levels by 2030. The preferred resource portfolio calls for the addition of 149 MW of wind, 258 MW of solar and 50 MW of battery storage to Colorado Electric's system. The final mix of resources will be determined by the results of a competitive solicitation ~~starting~~that started in July 2023. Colorado legislation allows electric utilities to own up to 50% of the renewable generation assets added to comply with the Clean Energy Plan.
Colorado Electric	Black Hills Colorado Electric, LLC, a direct, wholly-owned subsidiary of Black Hills ~~Utility~~Electric Parent Holdings, providing ~~natural gas~~electric services to customers in Colorado (doing business as Black Hills Energy).
Colorado Gas	Black Hills Colorado Gas, Inc., an indirect, wholly-owned subsidiary of Black Hills Utility Holdings, providing natural gas services to customers in Colorado (doing business as Black Hills Energy).
Common Use System	The Common Use System is a jointly operated transmission system we participated in with Basin Electric Power Cooperative and Powder River Energy Corporation. The Common Use System provides transmission service over these utilities' combined 230-kilovolt (kV) and limited 69-kV transmission facilities within areas of southwestern South Dakota and northeastern Wyoming.
Consolidated Indebtedness to Capitalization Ratio	Any indebtedness outstanding at such time, divided by capital at such time. Capital being consolidated net worth (excluding non-controlling interest) plus consolidated indebtedness (including letters of credit and certain guarantees issued) as defined within the current Revolving Credit Facility.
Cooling Degree Day	A cooling degree day is equivalent to each degree that the average of the high and low temperatures for a day is above 65 degrees. The warmer the climate, the greater the number of cooling degree days. Cooling degree days are used in the utility industry to measure the relative warmth 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.
CP Program	Commercial Paper Program

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CPUC	Colorado Public Utilities Commission
DRSPP	Dividend Reinvestment and Stock Purchase Plan
Dth	Dekatherm. A unit of energy equal to 10 therms or approximately one million British thermal units (MMBtu)
FASB	Financial Accounting Standards Board
Fitch	Fitch Ratings Inc.
GAAP	Accounting principles generally accepted in the United States of America
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 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.
HomeServe	We offer HomeServe products to our natural gas residential customers interested in purchasing additional home repair service plans.
Integrated Generation	Non-regulated power generation and mining businesses that are vertically integrated within our Electric Utilities segment.
Iowa Gas	Black Hills Iowa Gas Utility Company, LLC, a direct, wholly-owned subsidiary of Black Hills Utility Holdings, providing natural gas services to customers in Iowa (doing business as Black Hills Energy).
IPP	Independent Power Producer
IRS	United States Internal Revenue Service
Kansas Gas	Black Hills Kansas Gas Utility Company, LLC, a direct, wholly-owned subsidiary of Black Hills Utility Holdings, providing natural gas services to customers in Kansas (doing business as Black Hills Energy).
kV	~~Kilovolt~~
LIBOR	London Interbank Offered Rate
~~MEAN~~	~~Municipal Energy Agency of Nebraska~~
MMBtu	Million British thermal units
Moody's	Moody's Investors Service, Inc.
MW	Megawatts
MWh	Megawatt-hours
N/A	Not applicable
Nebraska Gas	Black Hills Nebraska Gas, LLC, an indirect, wholly-owned subsidiary of Black Hills Utility Holdings, providing natural gas services to customers in Nebraska (doing business as Black Hills Energy).
NOx	~~Nitrogen oxide~~
Northern Iowa Windpower	Northern Iowa Windpower, LLC, a 87.1 MW wind farm located near Joice, Iowa, previously owned by Black Hills Electric Generation. In March 2023, Black Hills Electric Generation completed the sale of Northern Iowa Windpower assets to a third-party.
OCI	Other Comprehensive Income
PPA	Power Purchase Agreement
~~Pueblo Airport Generation~~PTC	The 420 MW combined cycle gas-fired power generation plants jointly owned by Colorado Electric (220 MW) and Black Hills Colorado IPP (200 MW). Black Hills Colorado IPP operates this facility. The plants commenced operation on January 1, 2012.Production Tax Credit
Revolving Credit Facility	Our $750 million credit facility used to fund working capital needs, letters of credit and other corporate purposes, which was amended on May 9, 2023 and ~~restated on July 19, 2021, and now terminates~~will terminate on July 19, 2026.
RMNG	Rocky Mountain Natural Gas LLC, an indirect, wholly-owned subsidiary of Black Hills Utility Holdings, providing natural gas transmission and wholesale services in western Colorado (doing business as Black Hills Energy).
SEC	United States Securities and Exchange Commission
Service Guard Comfort Plan	Appliance protection plan that provides home appliance repair services through on-going monthly service agreements to residential utility customers.
S&P	S&P Global Ratings, a division of S&P Global Inc.
SOFR	Secured Overnight Financing Rate
South Dakota Electric	Black Hills Power, Inc., a direct, wholly-owned subsidiary of Black Hills Corporation, providing electric service to customers in Montana, South Dakota and Wyoming (doing business as Black Hills Energy).
SSIR	System Safety and Integrity Rider
Tech Services	Non-regulated product lines delivered by our Utilities that 1) provide electrical system construction services to large industrial customers of our electric utilities, and 2) serve gas transportation customers throughout its service territory by constructing and maintaining customer-owned gas infrastructure facilities, typically through one-time contracts.
Utilities	Black Hills' Electric and Gas Utilities

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Wind Capacity Factor	Measures the amount of electricity a wind turbine produces in a given time period relative to its maximum potential.
Winter Storm Uri	February 2021 winter weather event that caused extreme cold temperatures in the central United States and led to unprecedented fluctuations in customer demand and market pricing for natural gas and energy.
WPSC	Wyoming Public Service Commission
WRDC	Wyodak Resources Development Corp., a direct, wholly-owned subsidiary of Black Hills Non-regulated Holdings, providing coal supply primarily to five on-site, mine-mouth generating facilities (doing business as Black Hills Energy).
Wygen I	A mine-mouth, coal-fired power plant with a total capacity of 90 MW located at our Gillette, Wyoming energy complex. Black Hills Wyoming owns a 76.5% of the facility and Municipal Energy Agency of Nebraska (MEAN) owns the remaining 23.5%.
~~Wygen II~~	~~A mine-mouth, coal-fired power plant owned by Wyoming Electric with a total capacity of 95 MW located at our Gillette, Wyoming energy complex.~~
~~Wygen III~~	A mine-mouth, coal-fired power plant operated by South Dakota Electric with a total capacity of 110 MW located at our Gillette, Wyoming energy complex. South Dakota Electric owns 52% of the power plant, MDU owns 25% and the City of Gillette owns the remaining 23%.
Wyodak Plant	The 362 MW mine-mouth, coal-fired generating facility near Gillette, Wyoming, jointly owned by PacifiCorp (80%) and South Dakota Electric (20%). Our WRDC mine supplies all of the fuel for the facility.
Wyoming Electric	Cheyenne Light, Fuel and Power Company, a direct, wholly-owned subsidiary of Black Hills Corporation, providing electric service to customers in the Cheyenne, Wyoming area (doing business as Black Hills Energy).
Wyoming Gas	Black Hills Wyoming Gas, LLC, an indirect and wholly-owned subsidiary of Black Hills Utility Holdings, providing natural gas services to customers in Wyoming (doing business as Black Hills Energy).
Wyoming Integrity Rider	The Wyoming Integrity Rider (WIR) is a WPSC-approved tariff that allows us to recover costs from customers associated with ongoing infrastructure replacement, gas meter and yard line replacement projects driven by federal regulation.

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FORWARD-LOOKING INFORMATION

This Quarterly Report on Form 10-Q includes “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. We make these forward-looking statements in reliance on the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995. These forward-looking statements are based on assumptions which we believe are reasonable based on current expectations and projections about future events and industry conditions and trends affecting our business. However, whether actual results and developments will conform to our expectations and predictions is subject to a number of risks and uncertainties that, among other things, could cause actual results to differ materially from those contained in the forward-looking statements, including without limitation, the risk factors described in Item 1A of Part I of our 2022 Annual Report on Form 10-K, Part II, Item 1A of this Quarterly Report on Form 10-Q and other reports that we file with the SEC from time to time, and the following:

•

Our ability to obtain adequate cost recovery for our utility operations through regulatory proceedings and favorable rulings on periodic applications to recover costs for capital additions, plant retirements and decommissioning, fuel, transmission, purchased power, and other operating costs and the timing in which new rates would go into effect;

•

Our ability to complete our capital program in a cost-effective and timely manner;

•

Our ability to execute on our strategy;

•

Our ability to successfully execute our financing plans;

•

The effects of changing interest rates;

•

Our ability to achieve our greenhouse gas emissions intensity reduction goals;

•

Board of Directors’ approval of any future quarterly dividends;

•

The impact of future governmental regulation;

•

Our ability to overcome the impacts of supply chain disruptions on availability and cost of materials;

•

The effects of inflation and volatile energy prices; and

•

Other factors discussed from time to time in our filings with the SEC.

New factors that could cause actual results to differ materially from those described in forward-looking statements emerge from time-to-time, and it is not possible for us to predict all such factors, or the extent to which any such factor or combination of factors may cause actual results to differ from those contained in any forward-looking statement. We assume no obligation to update publicly any such forward-looking statements, whether as a result of new information, future events or otherwise.

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PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

BLACK HILLS CORPORATION

CONSOLIDATED STATEMENTS OF INCOME


(unaudited)	Three Months Ended March 31,						Three Months Ended September 30,						Nine Months Ended September 30,
	2023			2022			2023			2022			2023			2022
	(in thousands, except per share amounts)						(in thousands, except per share amounts)
Revenue	$	921,159		$	823,570		$	407,126		$	462,612		$	1,739,568		$	1,760,377

Operating expenses:
Fuel, purchased power and cost of natural gas sold		526,267			436,926			102,241			168,535			749,753			793,632
Operations and maintenance		140,988			136,132			125,767			134,449			412,522			403,549
Depreciation, depletion and amortization		61,643			60,463			64,878			64,019			191,235			188,610
Taxes - property and production		17,378			16,696			16,469			16,130			49,888			49,365
Total operating expenses		746,276			650,217			309,355			383,133			1,403,398			1,435,156

Operating income		174,883			173,353			97,771			79,479			336,170			325,221

Other income (expense):
Interest expense incurred net of amounts capitalized (including amortization of debt issuance costs, premiums and discounts)		(44,065	)		(38,821	)
Interest expense incurred net of amounts capitalized								(44,477	)		(40,580	)		(131,809	)		(118,454	)
Interest income		561			276			3,479			561			5,786			1,126
Other income, net		674			704
Other income (expense), net								(647	)		464			(1,513	)		2,731
Total other income (expense)		(42,830	)		(37,841	)		(41,645	)		(39,555	)		(127,536	)		(114,597	)

Income before income taxes		132,053			135,512			56,126			39,924			208,634			210,624
Income tax (expense)		(14,673	)		(14,488	)		(7,366	)		(2,090	)		(15,950	)		(15,920	)
Net income		117,380			121,024			48,760			37,834			192,684			194,704
Net income attributable to non-controlling interest		(3,296	)		(3,498	)		(3,377	)		(2,861	)		(10,164	)		(8,790	)
Net income available for common stock	$	114,084		$	117,526		$	45,383		$	34,973		$	182,520		$	185,914

Earnings per share of common stock:
Earnings per share, Basic	$	1.73		$	1.82		$	0.67		$	0.54		$	2.74		$	2.87
Earnings per share, Diluted	$	1.73		$	1.82		$	0.67		$	0.54		$	2.74		$	2.86

Weighed average common shares outstanding:
Weighted average common shares outstanding:
Basic		66,036			64,565			67,315			64,876			66,652			64,722
Diluted		66,132			64,721			67,389			65,061			66,725			64,910

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

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BLACK HILLS CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME


(unaudited)	Three Months Ended March 31,						Three Months Ended September 30,						Nine Months Ended September 30,
	2023			2022			2023			2022			2023			2022
	(in thousands)						(in thousands)
Net income	$	117,380		$	121,024		$	48,760		$	37,834		$	192,684		$	194,704

Other comprehensive income (loss), net of tax;
Reclassification adjustments of benefit plan liability - prior service cost (net of tax of $0 and $6, respectively)		-			(18	)
Reclassification adjustments of benefit plan liability - net loss (net of tax of $(16) and $(45), respectively)		28			143
Reclassification adjustments of benefit plan liability - prior service cost (net of tax of $--, $8, $-- and $22, respectively)								-			(16	)		-			(48	)
Reclassification adjustments of benefit plan liability - net loss (net of tax of $(19), $(66), $(62) and $(179), respectively)								24			122			67			384
Derivative instruments designated as cash flow hedges:
Reclassification of net realized (gains) losses on settled/amortized interest rate swaps (net of tax of $(150) and $(177), respectively)		563			536
Net unrealized gains (losses) on commodity derivatives (net of tax of $268 and $(340), respectively)		(855	)		1,047
Reclassification of net realized (gains) losses on settled commodity derivatives (net of $(466) and $552, respectively)		1,484			(1,702	)
Reclassification of net realized (gains) losses on settled/amortized interest rate swaps (net of tax of $(162), $(134), $(489) and $(549), respectively)								550			578			1,649			1,589
Net unrealized gains (losses) on commodity derivatives (net of tax of $58, $(559), $291 and $(165), respectively)								(195	)		1,776			(937	)		509
Reclassification of net realized (gains) losses on settled commodity derivatives (net of tax of $(8), $10, $(592) and $881, respectively)								26			(33	)		1,881			(2,739	)
Other comprehensive income, net of tax		1,220			6			405			2,427			2,660			(305	)

Comprehensive income		118,600			121,030			49,165			40,261			195,344			194,399
Less: comprehensive income attributable to non-controlling interest		(3,296	)		(3,498	)		(3,377	)		(2,861	)		(10,164	)		(8,790	)
Comprehensive income available for common stock	$	115,304		$	117,532		$	45,788		$	37,400		$	185,180		$	185,609

See Note 9 for additional disclosures.

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

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BLACK HILLS CORPORATION

CONSOLIDATED BALANCE SHEETS


(unaudited)	As of						As of
	March 31, 2023			December 31, 2022			September 30, 2023			December 31, 2022
	(in thousands)						(in thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	39,365		$	21,430		$	594,289		$	21,430
Restricted cash and equivalents		5,765			5,555			6,213			5,555
Accounts receivable, net		477,089			508,192			228,830			508,192
Materials, supplies and fuel		129,960			207,421			168,079			207,421
Derivative assets, current		153			582			126			582
Income tax receivable, net		17,772			17,637			17,749			17,637
Regulatory assets, current		214,838			260,312			191,746			260,312
Other current assets		33,376			50,579			33,242			50,579
Total current assets		918,318			1,071,708			1,240,274			1,071,708

Property, plant and equipment		8,466,173			8,374,790			8,767,954			8,374,790
Less: accumulated depreciation and depletion		(1,628,772	)		(1,576,842	)		(1,755,606	)		(1,576,842	)
Total property, plant and equipment, net		6,837,401			6,797,948			7,012,348			6,797,948

Other assets:
Goodwill		1,299,454			1,299,454			1,299,454			1,299,454
Intangible assets, net		9,296			9,589			8,708			9,589
Regulatory assets, non-current		347,031			392,669			313,113			392,669
Other assets, non-current		48,636			46,862			59,031			46,862
Total other assets, non-current		1,704,417			1,748,574			1,680,306			1,748,574

TOTAL ASSETS	$	9,460,136		$	9,618,230		$	9,932,928		$	9,618,230

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

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BLACK HILLS CORPORATION

CONSOLIDATED BALANCE SHEETS

(Continued)


(unaudited)	As of						As of
	March 31, 2023			December 31, 2022			September 30, 2023			December 31, 2022
	(in thousands)						(in thousands)
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	173,221		$	310,020		$	124,033		$	310,020
Accrued liabilities		228,861			243,457			257,458			243,457
Derivative liabilities, current		1,729			6,600			2,193			6,600
Regulatory liabilities, current		110,100			46,013			93,988			46,013
Notes payable		-			535,600			-			535,600
Current maturities of long-term debt		525,000			525,000			1,125,000			525,000
Total current liabilities		1,038,911			1,666,690			1,602,672			1,666,690

Long-term debt, net of current maturities		3,954,409			3,607,340			3,799,510			3,607,340

Deferred credits and other liabilities:
Deferred income tax liabilities, net		535,852			508,941			530,985			508,941
Regulatory liabilities, non-current		466,961			472,560			468,969			472,560
Benefit plan liabilities		117,765			116,742			119,046			116,742
Other deferred credits and other liabilities		154,507			156,062			152,174			156,062
Total deferred credits and other liabilities		1,275,085			1,254,305			1,271,174			1,254,305

Commitments, contingencies and guarantees (Note 3)

Equity:
Stockholder's equity -
Common stock $1 par value; 100,000,000 shares authorized; issued 66,670,709 and 66,140,396 shares, respectively		66,671			66,140
Common stock $1 par value; 100,000,000 shares authorized; issued 68,046,262 and 66,140,396 shares, respectively								68,046			66,140
Additional paid-in capital		1,911,476			1,882,653			1,994,439			1,882,653
Retained earnings		1,136,844			1,064,122			1,121,196			1,064,122
Treasury stock, at cost - 41,114 and 36,726 shares, respectively		(2,697	)		(2,435	)
Treasury stock, at cost - 54,428 and 36,726 shares, respectively								(3,457	)		(2,435	)
Accumulated other comprehensive income (loss)		(14,347	)		(15,567	)		(12,907	)		(15,567	)
Total stockholders' equity		3,097,947			2,994,913			3,167,317			2,994,913
Non-controlling interest		93,784			94,982			92,255			94,982
Total equity		3,191,731			3,089,895			3,259,572			3,089,895

TOTAL LIABILITIES AND TOTAL EQUITY	$	9,460,136		$	9,618,230		$	9,932,928		$	9,618,230

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

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BLACK HILLS CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS


(unaudited)	Three Months Ended March 31,						Nine Months Ended September 30,
	2023			2022			2023			2022
Operating activities:	(in thousands)						(in thousands)
Net income	$	117,380		$	121,024		$	192,684		$	194,704
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization		61,643			60,463			191,235			188,610
Deferred financing cost amortization		2,410			2,475			6,928			7,430
Stock compensation		1,784			3,638			4,563			6,779
Deferred income taxes		14,858			14,462			16,114			16,062
Employee benefit plans		3,021			1,173			7,929			2,677
Other adjustments, net		(2,816	)		5,337			(6,099	)		(10,243	)
Changes in certain operating assets and liabilities:
Materials, supplies and fuel		76,122			34,995			43,546			(88,405	)
Accounts receivable and other current assets		28,729			(71,241	)		302,764			64,280
Accounts payable and other current liabilities		(127,233	)		(8,422	)		(186,500	)		5,963
Regulatory assets		154,666			98,528			199,093			118,330
Other operating activities, net		(1,819	)		1,689			(16,205	)		(11,900	)
Net cash provided by operating activities		328,745			264,121			756,052			494,287

Investing activities:
Property, plant and equipment additions		(119,105	)		(136,779	)		(421,770	)		(466,302	)
Other investing activities		17,600			(1,065	)		17,985			(19	)
Net cash (used in) investing activities		(101,505	)		(137,844	)		(403,785	)		(466,321	)

Financing activities:
Dividends paid on common stock		(41,362	)		(38,533	)		(125,446	)		(115,850	)
Common stock issued		27,383			3,791			107,380			20,027
Net borrowings (payments) of Revolving Credit Facility and CP Program		(535,600	)		(78,700	)		(535,600	)		81,170
Long-term debt - issuance		350,000			-			800,000			-
Distributions to non-controlling interests		(4,494	)		(4,420	)		(12,891	)		(11,678	)
Other financing activities		(5,022	)		(878	)		(12,193	)		1,647
Net cash (used in) financing activities		(209,095	)		(118,740	)
Net cash provided by (used in) financing activities								221,250			(24,684	)

Net change in cash, restricted cash and cash equivalents		18,145			7,537			573,517			3,282

Cash, restricted cash and cash equivalents beginning of period		26,985			13,810			26,985			13,810
Cash, restricted cash and cash equivalents end of period	$	45,130		$	21,347		$	600,502		$	17,092

Supplemental cash flow information:
Cash (paid) refunded during the period:
Interest (net of amounts capitalized)	$	(27,569	)	$	(23,605	)	$	(108,813	)	$	(98,227	)
Income taxes		49			-			51			746
Non-cash investing and financing activities:
Accrued property, plant and equipment purchases at March 31,		42,102			39,559
Accrued property, plant and equipment purchases at September 30,								52,984			42,687

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

Table of Contents

BLACK HILLS CORPORATION

CONSOLIDATED STATEMENTS OF EQUITY

(unaudited)
Common Stock

Treasury Stock

(in thousands except share amounts)
Shares

Value

Shares

Value

Additional Paid in Capital

Retained Earnings

AOCI

Non-controlling Interest

Total

December 31, 2022

66,140,396

$
66,140

36,726

$
(2,435
)
$
1,882,653

$
1,064,122

$
(15,567
)
$
94,982

$
3,089,895

Net income

-

-

-

-

-

114,084

-

3,296

117,380

Other comprehensive income, net of tax

-

-

-

-

-

-

1,220

-

1,220

Dividends on common stock ($0.625 per share)

-

-

-

-

-

(41,362
)

-

-

(41,362
)
Share-based compensation

84,735

85

4,388

(262
)

1,886

-

-

-

1,709

Issuance of common stock

445,578

446

-

-

27,273

-

-

-

27,719

Issuance costs

-

-

-

-

(336
)

-

-

-

(336
)
Distributions to non-controlling interest

-

-

-

-

-

-

-

(4,494
)

(4,494
)
March 31, 2023

66,670,709

$
66,671

41,114

$
(2,697
)
$
1,911,476

$
1,136,844

$
(14,347
)
$
93,784

$
3,191,731


(unaudited)	Common Stock				Treasury Stock																					Common Stock				Treasury Stock
(in thousands except share amounts)	Shares		Value		Shares			Value			Additional Paid in Capital			Retained Earnings			AOCI			Non-controlling Interest			Total			Shares		Value		Shares		Value			Additional Paid in Capital			Retained Earnings			AOCI			Non-controlling Interest			Total
December 31, 2021		64,793,095	$	64,793		54,078		$	(3,509	)	$	1,783,436		$	962,458		$	(20,084	)	$	100,029		$	2,887,123
December 31, 2022																											66,140,396	$	66,140		36,726	$	(2,435	)	$	1,882,653		$	1,064,122		$	(15,567	)	$	94,982		$	3,089,895
Net income		-		-		-			-			-			117,526			-			3,498			121,024			-		-		-		-			-			114,084			-			3,296			117,380
Other comprehensive income, net of tax		-		-		-			-			-			-			6			-			6			-		-		-		-			-			-			1,220			-			1,220
Dividends on common stock ($0.595 per share)		-		-		-			-			-			(38,533	)		-			-			(38,533	)
Dividends on common stock ($0.625 per share)																											-		-		-		-			-			(41,362	)		-			-			(41,362	)
Share-based compensation		425		-		(34,393	)		2,222			(191	)		-			-			-			2,031			84,735		85		4,388		(262	)		1,886			-			-			-			1,709
Issuance of common stock		55,707		56		-			-			3,776			-			-			-			3,832			445,578		446		-		-			27,273			-			-			-			27,719
Issuance costs		-		-		-			-			(41	)		-			-			-			(41	)		-		-		-		-			(336	)		-			-			-			(336	)
Distributions to non-controlling interest		-		-		-			-			-			-			-			(4,420	)		(4,420	)		-		-		-		-			-			-			-			(4,494	)		(4,494	)
March 31, 2022		64,849,227	$	64,849		19,685		$	(1,287	)	$	1,786,980		$	1,041,451		$	(20,078	)	$	99,107		$	2,971,022
March 31, 2023																											66,670,709	$	66,671		41,114	$	(2,697	)	$	1,911,476		$	1,136,844		$	(14,347	)	$	93,784		$	3,191,731
Net income																											-		-		-		-			-			23,053			-			3,491			26,544
Other comprehensive income, net of tax																											-		-		-		-			-			-			1,035			-			1,035
Dividends on common stock ($0.625 per share)																											-		-		-		-			-			(41,752	)		-			-			(41,752	)
Share-based compensation																											8,492		8		7,509		(470	)		2,888			-			-			-			2,426
Issuance of common stock																											436,202		436		-		-			27,274			-			-			-			27,710
Issuance costs																											-		-		-		-			(404	)		-			-			-			(404	)
Distributions to non-controlling interest																											-		-		-		-			-			-			-			(4,523	)		(4,523	)
June 30, 2023																											67,115,403	$	67,115		48,623	$	(3,167	)	$	1,941,234		$	1,118,145		$	(13,312	)	$	92,752		$	3,202,767
Net income																											-		-		-		-			-			45,383			-			3,377			48,760
Other comprehensive income, net of tax																											-		-		-		-			-			-			405			-			405
Dividends on common stock ($0.625 per share)																											-		-		-		-			-			(42,332	)		-			-			(42,332	)
Share-based compensation																											15		-		5,805		(290	)		1,445			-			-			-			1,155
Issuance of common stock																											930,844		931		-		-			52,433												53,364
Issuance costs																											-		-		-		-			(673	)		-			-			-			(673	)
Distributions to non-controlling interest																											-		-		-		-			-			-			-			(3,874	)		(3,874	)
September 30, 2023																											68,046,262	$	68,046		54,428	$	(3,457	)	$	1,994,439		$	1,121,196		$	(12,907	)	$	92,255		$	3,259,572

Table of Contents


(unaudited)	Common Stock				Treasury Stock
(in thousands except share amounts)	Shares		Value		Shares			Value			Additional Paid in Capital			Retained Earnings			AOCI			Non-controlling Interest			Total
December 31, 2021		64,793,095	$	64,793		54,078		$	(3,509	)	$	1,783,436		$	962,458		$	(20,084	)	$	100,029		$	2,887,123
Net income		-		-		-			-			-			117,526			-			3,498			121,024
Other comprehensive income, net of tax		-		-		-			-			-			-			6			-			6
Dividends on common stock ($0.595 per share)		-		-		-			-			-			(38,533	)		-			-			(38,533	)
Share-based compensation		425		-		(34,393	)		2,222			(191	)		-			-			-			2,031
Issuance of common stock		55,707		56		-			-			3,776			-			-			-			3,832
Issuance costs		-		-		-			-			(41	)		-			-			-			(41	)
Distributions to non-controlling interest		-		-		-			-			-			-			-			(4,420	)		(4,420	)
March 31, 2022		64,849,227	$	64,849		19,685		$	(1,287	)	$	1,786,980		$	1,041,451		$	(20,078	)	$	99,107		$	2,971,022
Net income		-		-		-			-			-			33,415			-			2,431			35,846
Other comprehensive income, net of tax		-		-		-			-			-			-			(2,738	)		-			(2,738	)
Dividends on common stock ($0.595 per share)		-		-		-			-			-			(38,603	)		-			-			(38,603	)
Share-based compensation		39,066		39		4,006			(255	)		5,370			-			-			-			5,154
Issuance of common stock		216,885		217		-			-			16,353			-			-			-			16,570
Issuance costs		-		-		-			-			(266	)		-			-			-			(266	)
Distributions to non-controlling interest		-		-		-			-			-			-			-			(4,184	)		(4,184	)
June 30, 2022		65,105,178	$	65,105		23,691		$	(1,542	)	$	1,808,437		$	1,036,263		$	(22,816	)	$	97,354		$	2,982,801
Net income		-		-		-			-			-			34,973			-			2,861			37,834
Other comprehensive income, net of tax		-		-		-			-			-			-			2,427			-			2,427
Dividends on common stock ($0.595 per share)		-		-		-			-			-			(38,714	)		-			-			(38,714	)
Share-based compensation		27		-		2,517			(173	)		2,724			-			-			-			2,551
Issuance costs		-		-		-			-			(68	)		-			-			-			(68	)
Distributions to non-controlling interest		-		-		-			-			-			-			-			(3,074	)		(3,074	)
September 30, 2022		65,105,205	$	65,105		26,208		$	(1,715	)	$	1,811,093		$	1,032,522		$	(20,389	)	$	97,141		$	2,983,757

Table of Contents

BLACK HILLS CORPORATION

Condensed Notes to Consolidated Financial Statements

(unaudited)

(Reference is made to Notes to Consolidated Financial Statements

included in the Company’s 2022 Annual Report on Form 10-K)

(1)

Management’s Statement

The unaudited Consolidated Financial Statements included herein have been prepared by Black Hills Corporation (together with our subsidiaries the “Company”, “us”, “we” or “our”), pursuant to the rules and regulations of the SEC. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been condensed or omitted pursuant to such rules and regulations; however, we believe that the footnotes adequately disclose the information presented. These Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and the notes included in our 2022 Annual Report on Form 10-K.

Use of Estimates and Basis of Presentation

The information furnished in the accompanying Consolidated 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,~~September 30, 2023, December 31, 2022 and ~~March 31,~~September 30, 2022 financial information. Certain lines of business in which we operate are highly seasonal, and our interim results of operations are not necessarily indicative of the results of operations to be expected for an entire year.

~~Recently Issued Accounting Standards~~

~~Facilitation of the Effects of Reference Rate Reform on Financial Reporting, ASU 2020-04~~

~~In March 2020, the FASB issued ASU 2020-04,~~ ~~Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting,~~ which was subsequently amended by ASU 2021-01 and ASU 2022-06. The standard provides relief for companies preparing for discontinuation of interest rates, such as LIBOR, and allows optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria are met. The amendments in this update are elective and are effective upon the ASU issuance through December 31, 2024. We are currently evaluating if we will apply the optional guidance as we assess the impact of the discontinuance of LIBOR on our current arrangements. We do not expect the ASU to have a material impact on our financial position, results of operations and cash flows.

~~Table of Contents~~

(2)

Regulatory Matters

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


	As of			As of			As of			As of
	March 31, 2023			December 31, 2022			September 30, 2023			December 31, 2022
Regulatory assets
Winter Storm Uri ~~(a)~~	$	253,835		$	347,980		$	225,052		$	347,980
Deferred energy and fuel cost adjustments ~~(b)~~		79,020			72,580			59,129			72,580
Deferred gas cost adjustments ~~(b)~~		16,047			12,147			8,048			12,147
Gas price derivatives ~~(b)~~		-			8,793			3,849			8,793
Deferred taxes on AFUDC ~~(b)~~		7,482			7,333			7,180			7,333
Employee benefit plans and related deferred taxes ~~(c)~~		88,710			89,259			87,423			89,259
Environmental ~~(b)~~		1,341			1,343			2,868			1,343
Loss on reacquired debt ~~(b)~~		18,764			19,213			17,865			19,213
Deferred taxes on flow through accounting ~~(b)~~		74,022			69,529			69,259			69,529
Decommissioning costs ~~(b)~~		2,850			3,472			2,407			3,472
Other regulatory assets ~~(b)~~		19,798			21,332			21,779			21,332
Total regulatory assets		561,869			652,981			504,859			652,981
Less current regulatory assets		(214,838	)		(260,312	)		(191,746	)		(260,312	)
Regulatory assets, non-current	$	347,031		$	392,669		$	313,113		$	392,669

Regulatory liabilities
Deferred energy and gas costs ~~(b)~~	$	106,030		$	41,722		$	91,273		$	41,722
Employee benefit plan costs and related deferred taxes ~~(c)~~		33,839			34,258			33,006			34,258
Cost of removal ~~(b)~~		177,453			175,614			179,208			175,614
Excess deferred income taxes ~~(c)~~		248,126			254,833			250,390			254,833
Other regulatory liabilities ~~(c)~~		11,613			12,146			9,080			12,146
Total regulatory liabilities		577,061			518,573			562,957			518,573
Less current regulatory liabilities		(110,100	)		(46,013	)		(93,988	)		(46,013	)
Regulatory liabilities, non-current	$	466,961		$	472,560		$	468,969		$	472,560

~~(a)~~

~~Timing of Winter Storm Uri incremental cost recovery and associated carrying costs vary by jurisdiction.~~

~~(b)~~

~~Recovery or repayment of costs, but we are not 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.~~

Regulatory Activity

Except as discussed below, there have been no other significant changes to our Regulatory Matters from those previously disclosed in Note 2 of the Notes to the Consolidated Financial Statements in our 2022 Annual Report on Form 10-K.

Table of Contents

Colorado Gas

RMNG Rate Review

On ~~April 7,~~July 12, 2023, ~~RMNG filed~~the CPUC approved a settlement agreement ~~with the CPUC~~ for ~~its~~RMNG's rate review filed on October 7, 2022. The agreement is expected to generate $8.2 million in new annual revenue and establishes a weighted average cost of capital of 6.93% with a capital structure that reflects an equity range of 50% to 52%, a debt range of 50% to 48% and a return on equity range of 9.5% to 9.7%. The settlement also shifts $8.3 million of SSIR revenues to base rates and terminates the SSIR. New rates were effective July 15, 2023.

Colorado Gas Rate Review

On May 9, 2023, Colorado Gas filed a rate review with the CPUC seeking recovery of significant infrastructure investments in its 10,000-mile natural gas pipeline system. The rate review requests $27 million in new annual revenue with a capital structure of 51% equity and 49% debt and a return on equity of 10.49%. The request seeks to finalize rates in the first quarter of 2024.

Wyoming Gas

On May 18, 2023, Wyoming Gas filed a rate review with the WPSC seeking recovery of significant infrastructure investments in its 6,400-mile natural gas pipeline system. On October 13, 2023, Wyoming Gas filed a settlement agreement with the WPSC for a general rate increase. The agreement is ~~awaiting~~expected to generate $13.9 million in new annual revenue with a ~~decision by an administrative law judge, with~~capital structure of 51% equity, 49% debt and a return on equity of 9.85%. Subject to WPSC approval, the agreement includes new rates ~~expected in~~effective January 1, 2024 and a four-year extension of the ~~third quarter of 2023.~~Wyoming Integrity Rider.

Wyoming Electric

On June 1, 2022, Wyoming Electric filed a rate review with the WPSC seeking recovery of significant infrastructure investments in its ~~1330~~1,330-mile electric distribution and 59-mile electric transmission systems. On January 26, 2023, the WPSC approved a settlement agreement with intervening parties for a general rate increase. The settlement is expected to generate $8.7 million in new annual revenue with a capital structure of 52% equity, ~~and~~ 48% debt and a return on equity of 9.75%. New rates were effective March 1, 2023. The agreement also includes approval of a new rider that will be filed annually to recover transmission ~~investment~~investments and expenses.

~~Table of Contents~~

(3)

Commitments, Contingencies and Guarantees

~~There~~Except as described below, there have been no significant changes to commitments, contingencies and guarantees from those previously disclosed in Note 3 of our Notes to the Consolidated Financial Statements in our 2022 Annual Report on Form 10-K.

GT Resources, LLC v. Black Hills Corporation, Case No. 2020CV30751 (U.S. District Court for the City and County of Denver, Colorado)

On April 13, 2022, a jury awarded $41 million for claims made by GT Resources, LLC (“GTR”) against BHC and two of its subsidiaries (Black Hills Exploration and Production, Inc. and Black Hills Gas Resources, Inc.), which ceased oil and natural gas operations in 2018 as part of BHC’s decision to exit the exploration and production business. The claims involved a dispute over a 2.3 million-acre concession award in Costa Rica which was acquired by a BHC subsidiary in 2003. GTR retained rights to receive a royalty interest on any hydrocarbon production from the concession upon the occurrence of contingent events. GTR contended that BHC and its subsidiaries failed to adequately pursue the opportunity and failed to transfer the concession to GTR. We appealed this verdict to the Colorado Court of Appeals. On October 19, 2023, the Appellate Court reversed and remanded the case with directions limiting any retrial to the narrow issue of whether there was improper interference with the prospective conveyance of the concession. We continue to believe this lawsuit has no merit and will vigorously defend it. At this time, we do not believe any losses from this matter will have a material impact on our financial position, results of operations and cash flows.

Gain Contingency - Wygen 1 Business Interruption Insurance Recovery

In September 2021, Wygen I experienced an unplanned outage that continued until December 2021. For the year ended December 31, 2021, the outage resulted in lost revenue at our subsidiaries Black Hills Wyoming and WRDC. A claim for these losses was submitted under our business interruption insurance policy. During the third quarter of 2023, we recovered $5.0 million from our business interruption insurance which was recognized as Revenue in our Consolidated Statements of Income for the three and nine months ended September 30, 2023.

Table of Contents

(4)

~~Revenue~~Revenue

The following tables depict the disaggregation of revenue, including intercompany revenue, from contracts with customers by customer type and timing of revenue recognition for each of the reportable segments for the three and nine months ended ~~March 31,~~September 30, 2023 and 2022. Sales tax and other similar taxes are excluded from revenues.


Three Months Ended March 31, 2023	Electric Utilities		Gas Utilities		Inter-company Revenues			Total
Three Months Ended September 30, 2023										Electric Utilities		Gas Utilities		Inter-segment Revenues			Total
Customer types:	(in thousands)									(in thousands)
Retail	$	174,903	$	635,545	$	-		$	810,448	$	191,029	$	120,803	$	-		$	311,832
Transportation		-		52,843		(115	)		52,728		-		42,654		(114	)		42,540
Wholesale		9,398		-		-			9,398		9,441		-		-			9,441
Market - off-system sales		16,124		281		-			16,405		12,999		25		-			13,024
Transmission/Other		17,404		10,023		(4,351	)		23,076		18,092		9,607		(4,374	)		23,325
Revenue from contracts with customers	$	217,829	$	698,692	$	(4,466	)	$	912,055	$	231,561	$	173,089	$	(4,488	)	$	400,162
Other revenues		880		8,224		-			9,104		5,768		1,196		-			6,964
Total revenues	$	218,709	$	706,916	$	(4,466	)	$	921,159	$	237,329	$	174,285	$	(4,488	)	$	407,126

Timing of revenue recognition:
Services transferred at a point in time	$	8,657	$	-	$	-		$	8,657	$	7,843	$	-	$	-		$	7,843
Services transferred over time		209,172		698,692		(4,466	)		903,398		223,718		173,089		(4,488	)		392,319
Revenue from contracts with customers	$	217,829	$	698,692	$	(4,466	)	$	912,055	$	231,561	$	173,089	$	(4,488	)	$	400,162

Three Months Ended March 31, 2022
Electric Utilities

Gas Utilities

Inter-company Revenues

Total

Customer types:
(in thousands)

Retail
$
172,806

$
561,013

$
-

$
733,819

Transportation

-

49,523

(99
)

49,424

Wholesale

10,275

-

-

10,275

Market - off-system sales

7,154

238

-

7,392

Transmission/Other

15,433

9,575

(4,149
)

20,859

Revenue from contracts with customers
$
205,668

$
620,349

$
(4,248
)
$
821,769

Other revenues

870

1,043

(112
)

1,801

Total revenues
$
206,538

$
621,392

$
(4,360
)
$
823,570

Timing of revenue recognition:

Services transferred at a point in time
$
7,113

$
-

$
-

$
7,113

Services transferred over time

198,555

620,349

(4,248
)

814,656

Revenue from contracts with customers
$
205,668

$
620,349

$
(4,248
)
$
821,769


Three Months Ended September 30, 2022	Electric Utilities		Gas Utilities		Inter-segment Revenues			Total
Customer types:	(in thousands)
Retail	$	211,489	$	157,203	$	-		$	368,692
Transportation		-		41,006		(99	)		40,907
Wholesale		13,667		-		-			13,667
Market - off-system sales		16,770		186		-			16,956
Transmission/Other		15,919		8,875		(4,148	)		20,646
Revenue from contracts with customers	$	257,845	$	207,270	$	(4,247	)	$	460,868
Other revenues		824		1,018		(98	)		1,744
Total revenues	$	258,669	$	208,288	$	(4,345	)	$	462,612

Timing of revenue recognition:
Services transferred at a point in time	$	7,928	$	-	$	-		$	7,928
Services transferred over time		249,917		207,270		(4,247	)		452,940
Revenue from contracts with customers	$	257,845	$	207,270	$	(4,247	)	$	460,868


Nine Months Ended September 30, 2023	Electric Utilities		Gas Utilities		Inter-segment Revenues			Total
Customer types:	(in thousands)
Retail	$	522,304	$	931,129	$	-		$	1,453,433
Transportation		-		131,410		(344	)		131,066
Wholesale		24,578		-		-			24,578
Market - off-system sales		37,487		349		-			37,836
Transmission/Other		54,727		28,833		(13,120	)		70,440
Revenue from contracts with customers	$	639,096	$	1,091,721	$	(13,464	)	$	1,717,353
Other revenues		10,015		12,200		-			22,215
Total revenues	$	649,111	$	1,103,921	$	(13,464	)	$	1,739,568

Timing of revenue recognition:
Services transferred at a point in time	$	24,344	$	-	$	-		$	24,344
Services transferred over time		614,752		1,091,721		(13,464	)		1,693,009
Revenue from contracts with customers	$	639,096	$	1,091,721	$	(13,464	)	$	1,717,353

1516

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Nine Months Ended September 30, 2022	Electric Utilities		Gas Utilities		Inter-segment Revenues			Total
Customer types:	(in thousands)
Retail	$	553,327	$	947,290	$	-		$	1,500,617
Transportation		-		125,196		(298	)		124,898
Wholesale		32,370		-		-			32,370
Market - off-system sales		32,590		602		-			33,192
Transmission/Other		46,535		27,794		(12,445	)		61,884
Revenue from contracts with customers	$	664,822	$	1,100,882	$	(12,743	)	$	1,752,961
Other revenues		4,764		2,967		(315	)		7,416
Total revenues	$	669,586	$	1,103,849	$	(13,058	)	$	1,760,377

Timing of revenue recognition:
Services transferred at a point in time	$	21,712	$	-	$	-		$	21,712
Services transferred over time		643,110		1,100,882		(12,743	)		1,731,249
Revenue from contracts with customers	$	664,822	$	1,100,882	$	(12,743	)	$	1,752,961

(5)

Financing

Shelf Registration Statement

We maintain an effective shelf registration statement with the SEC under which we may issue, from time to time, an unspecified amount of senior debt securities, subordinated debt securities, common stock, preferred stock, warrants and other securities. In anticipation of the approaching expiration of our previous shelf registration statement on Form S-3 originally filed on August 4, 2020 (Registration No. 333-240320), we filed a new shelf registration statement on Form S-3 on June 16, 2023 (Registration No. 333-272739).

Short-term Debt

Revolving Credit Facility and CP Program

On May 9, 2023, we amended and restated our corporate Revolving Credit Facility, which replaced LIBOR as a benchmark interest rate with the SOFR. The adoption of SOFR as a benchmark interest rate was in advance of the scheduled elimination of LIBOR as a benchmark interest rate on June 30, 2023. No other significant terms or conditions, including borrowing capacity, credit spreads or financial covenants were modified under these amendments and restatements.

Our Revolving Credit Facility and CP Program, which are classified as Notes payable on the Consolidated Balance Sheets, had the following borrowings, outstanding letters of credit, and available capacity (dollars in thousands): as of:


	March 31, 2023		December 31, 2022			September 30, 2023		December 31, 2022
Amount outstanding	$	—	$	535,600		$	—	$	535,600
Letters of credit (a)	$	2,401	$	24,626		$	3,707	$	24,626
Available capacity	$	747,599	$	189,774		$	746,293	$	189,774
Weighted average interest rates	N/A			4.88	%	N/A			4.88	%

(a)

Letters of credit are off-balance sheet commitments that reduce the borrowing capacity available on our corporate Revolving Credit Facility.

Revolving Credit Facility and CP Program borrowing activity was as follows (dollars in thousands):


	Three Months Ended March 31,						Nine Months Ended September 30,
	2023			2022			2023			2022
Maximum amount outstanding (based on daily outstanding balances)	$	548,700		$	429,000		$	548,700		$	508,200
Average amount outstanding (based on daily outstanding balances)	$	331,268		$	360,823		$	109,209		$	347,121
Weighted average interest rates		4.91	%		0.44	%		4.91	%		1.41	%

Long-term Debt

On September 15, 2023, we completed a public debt offering of $450 million, 6.15% senior unsecured notes due May 15, 2034. Proceeds from the offering, which were net of $7.2 million of deferred financing costs, were used for general corporate purposes. We also plan to use the proceeds from the offering, along with cash on hand, to repay all of our $525 million principal amount outstanding notes on their November 30, 2023 maturity date.

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On March 7, 2023, we completed a public debt offering of $350 million, 5.95% five year senior unsecured notes due March 15, 2028. The proceeds from the offering, which were net of $4.2 million of deferred financing costs, were used to repay notes outstanding under our CP Program and for other general corporate purposes.

Debt Covenants

Revolving Credit Facility

~~Under~~We were in compliance with all of our Revolving Credit Facility wecovenants as of September 30, 2023. We are required to maintain a Consolidated Indebtedness to Capitalization Ratio not to exceed 0.65 to 1.00. Subject to applicable cure periods, a violation of ~~any of these covenants~~this covenant would constitute an event of default that entitles the lenders to terminate their remaining commitments and accelerate all principal and interest outstanding. As of September 30, 2023, our Consolidated Indebtedness to Capitalization Ratio was 0.61 to 1.00.

~~We were in compliance with our covenants at March 31, 2023, as shown below:~~


	~~As of March 31, 2023~~	~~Covenant Requirement~~
~~Consolidated Indebtedness to Capitalization Ratio~~	~~59.1~~%	~~Less than~~ 65%

Wyoming Electric

~~Covenants~~Wyoming Electric was in compliance with all covenants within ~~Wyoming Electric's~~its financing agreements ~~require~~as of September 30, 2023. Wyoming Electric is required to maintain a debt to capitalization ratio of no more than 0.60 to 1.00. As of ~~March 31,~~September 30, 2023, ~~we were in compliance with these financial covenants.~~Wyoming Electric's debt to capitalization ratio was

0.53

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to 1.00.

Equity

At-the-Market Equity Offering Program

As previously disclosed, on August 4, 2020, we entered into an Amended and Restated Equity Distribution Sales Agreement ("Previous Sales Agreement") to sell shares of common stock up to an aggregate of $400 million, from time to time, through our ATM program utilizing our shelf registration statement. On June 16, 2023, in conjunction with the new shelf registration statement filing discussed above, we entered into a new Equity Distribution Sales Agreement ("Sales Agreement") and terminated the Previous Sales Agreement. The Sales Agreement, which is similar to the Previous Sales Agreement, allows us to sell shares of common stock up to an aggregate of $400 million through our ATM program.

ATM activity was as follows (net proceeds and issuance costs in millions):


	Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022		2023		2022
Proceeds, (net of issuance costs of $(0.3), $(0.0) respectively)	$	27.4	$	3.8
August 4, 2020 ATM Program
Proceeds, (net of issuance costs of $0, $0, $(0.5) and $(0.2), respectively)					$	-	$	-	$	48.5	$	20.2
Number of shares issued						-		-		775,225		272,592

June 16, 2023 ATM Program
Proceeds, (net of issuance costs of $(0.5), $0, $(0.6) and $0, respectively)					$	52.8	$	-	$	59.2	$	-
Number of shares issued						930,844		-		1,037,399		-

Total activity under both ATM Programs
Proceeds, (net of issuance costs of $(0.5), $0, $(1.1) and $(0.2), respectively)					$	52.8	$	-	$	107.7	$	20.2
Number of shares issued						930,844		-		1,812,624		272,592
Average price per share	$	62.21	$	68.79	$	57.33	$	-	$	60.02	$	74.84
Number of shares issued		445,578		55,707

AsShareholder Dividend Reinvestment and Stock Purchase Plan

Effective as of ~~March 31,~~July 7, 2023, ~~there~~we terminated our DRSPP. On July 10, 2023, we filed a post-effective amendment to amend the Registration Statement on Form S-3 (File No. 333-240319) filed with the SEC on August 4, 2020. The filing of this post-effective amendment de-registered all shares of common stock that were ~~34,040~~ ~~shares issued,~~issuable under the DRSPP but not ~~settled.~~sold as of July 7, 2023. With the termination of the DRSPP, a direct stock purchase plan was offered which allows shareholders to continue making share transactions. This plan is sponsored and administered solely by EQ Shareowner Services, our transfer agent.

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(6)

Earnings Per Share

A reconciliation of share amounts used to compute earnings per share in the accompanying Consolidated Statements of Income was as follows (in thousands, except per share amounts):


	Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022		2023		2022
Net income available for common stock	$	114,084	$	117,526	$	45,383	$	34,973	$	182,520	$	185,914

Weighted average shares - basic		66,036		64,565		67,315		64,876		66,652		64,722
Dilutive effect of:
Equity compensation		96		156		74		185		73		188
Weighted average shares - diluted		66,132		64,721		67,389		65,061		66,725		64,910

Earnings per share of common stock:
Earnings per share, Basic	$	1.73	$	1.82	$	0.67	$	0.54	$	2.74	$	2.87
Earnings per share, Diluted	$	1.73	$	1.82	$	0.67	$	0.54	$	2.74	$	2.86

The following securities were excluded from the diluted earnings per share computation because of their anti-dilutive nature (in thousands):


	Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022		2023		2022
Equity compensation		53		-		74		-		48		-
Restricted stock						-		-		-		-
Anti-dilutive shares		53		-		74		-		48		-

(7)

Risk Management and Derivatives

Market and Credit Risk Disclosures

Our activities in the energy industry expose us to a number of risks in the normal operations of our businesses. Depending on the activity, we are exposed to varying degrees of market risk and credit risk. Valuation methodologies for our derivatives are detailed within Note 1 of the Notes to the Consolidated Financial Statements in our 2022 Annual Report on Form 10-K.

Market Risk

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

•

Commodity price risk associated with our retail natural gas and wholesale electric power marketing activities and our fuel procurement for several of our gas-fired generation assets, which include market fluctuations due to unpredictable factors such as weather, geopolitical events, pandemics, market speculation, recession, inflation, pipeline constraints, and other factors that may impact natural gas and electric supply and demand; and

•

Interest rate risk associated with future debt, including reduced access to liquidity during periods of extreme capital markets volatility.

~~Table of Contents~~

Credit Risk

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

We attempt to mitigate our credit exposure by conducting business primarily with high credit quality entities, setting tenor and credit limits commensurate with counterparty financial strength, obtaining master netting agreements and mitigating credit exposure with less creditworthy counterparties through parental guarantees, cash collateral requirements, letters of credit and other security agreements.

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

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Derivatives and Hedging Activity

Our derivative and hedging activities included in the accompanying Consolidated Balance Sheets, Consolidated Statements of Income and Consolidated Statements of Comprehensive Income are detailed below and in Note 8.

The operations of our Utilities, including natural gas sold by our Gas Utilities and natural gas used by our Electric Utilities’ generation plants or those plants under PPAs where our Electric Utilities must provide the generation fuel (tolling agreements), expose our utility customers to natural gas price volatility. Therefore, as allowed or required by state utility commissions, we enter into commission approved hedging programs utilizing natural gas futures, options, over-the-counter swaps and basis swaps to reduce our customers’ underlying exposure to these fluctuations. These transactions are considered derivatives, and in accordance with accounting standards for derivatives and hedging, mark-to-market adjustments are recorded as Derivative assets or Derivative liabilities on the accompanying Consolidated Balance Sheets, net of balance sheet offsetting as permitted by GAAP.

For our regulated Utilities’ hedging plans, unrealized and realized gains and losses, as well as option premiums and commissions on these transactions, are recorded as Regulatory assets or Regulatory liabilities in the accompanying Consolidated Balance Sheets in accordance with the state regulatory commission guidelines. When the related costs are recovered through our rates, the hedging activity is recognized in the Consolidated Statements of Income.

We use wholesale power purchase and sale contracts to manage purchased power costs and load requirements associated with serving our electric customers. Periodically, certain wholesale energy contracts are considered derivative instruments due to not qualifying for the normal purchase and normal sales exception to derivative accounting. Changes in the fair value of these commodity derivatives are recognized in the Consolidated Statements of Income.

To support our Choice Gas Program customers, we buy, sell and deliver natural gas at competitive prices by managing commodity price risk. As a result of these activities, this area of our business is exposed to risks associated with changes in the market price of natural gas. We manage our exposure to such risks using over-the-counter and exchange traded options and swaps with counterparties in anticipation of forecasted purchases and sales during time frames ranging from ~~April~~October 2023 through October 2025. A portion of our over-the-counter swaps have been designated as cash flow hedges to mitigate the commodity price risk associated with deliveries under fixed price forward contracts to deliver gas to our Choice Gas Program customers. The gain or loss on these designated derivatives is reported in AOCI in the accompanying Consolidated Balance Sheets and reclassified into earnings in the same period that the underlying hedged item is recognized in earnings. Effectiveness of our hedging position is evaluated at least quarterly.

The contract or notional amounts and terms of the electric and natural gas derivative commodity instruments held at our Utilities are composed of both long and short positions. We had the following net long positions as of:


	March 31, 2023				December 31, 2022				September 30, 2023				December 31, 2022
	Notional Amounts (MMBtus)		Maximum Term (months) (a)		Notional Amounts (MMBtus)		Maximum Term (months) (a)		Notional Amounts (MMBtus)		Maximum Term (months) (a)		Notional Amounts (MMBtus)		Maximum Term (months) (a)
Natural gas futures purchased		-	N/A			630,000		3		1,730,000		6		630,000		3
Natural gas options purchased, net		-	N/A			1,790,000		3		7,780,000		6		1,790,000		3
Natural gas basis swaps purchased		-	N/A			900,000		3		1,730,000		6		900,000		3
Natural gas over-the-counter swaps, net (b)		3,270,000		26		4,460,000		24		5,610,000		24		4,460,000		24
Natural gas physical contracts, net (c)		3,881,190		12		17,864,412		12		21,323,455		7		17,864,412		12

(a)

Term reflects the maximum forward period hedged.

(b)

As of ~~March 31,~~September 30, 2023, ~~574,800~~2,979,300 MMBtus of natural gas over-the-counter swaps purchases were designated as cash flow hedges.

(c)

Volumes exclude derivative contracts that qualify for the normal purchases and normal sales exception permitted by GAAP.

~~Table of Contents~~

We have certain derivative contracts which contain credit provisions. These credit provisions may require the Company to post collateral when credit exposure to the Company is in excess of a negotiated line of unsecured credit. At ~~March 31,~~September 30, 2023, the Company posted $0.6 million related to such provisions, which is included in Other current assets on the Consolidated Balance Sheets.

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Derivatives by Balance Sheet Classification

As required by accounting standards for derivatives and hedges, fair values within the following tables are presented on a gross basis aside from the netting of asset and liability positions. Netting of positions is permitted in accordance with accounting standards for offsetting and under terms of our master netting agreements that allow us to settle positive and negative positions.

The following table presents the fair value and balance sheet classification of our derivative instruments (in thousands) as of:


	Balance Sheet Location	March 31, 2023			December 31, 2022			Balance Sheet Location	September 30, 2023			December 31, 2022
Derivatives designated as hedges:
Asset derivative instruments:
Current commodity derivatives	Derivative assets, current	$	-		$	118		Derivative assets, current	$	-		$	118
Noncurrent commodity derivatives	Other assets, non-current		-			198		Other assets, non-current		(18	)		198
Liability derivative instruments:
Current commodity derivatives	Derivative liabilities, current		(543	)		(1,703	)	Derivative liabilities, current		143			(1,703	)
Noncurrent commodity derivatives	Other assets, non-current		(2	)		-		Other assets, non-current		(20	)		-
Total derivatives designated as hedges		$	(545	)	$	(1,387	)		$	105		$	(1,387	)

Derivatives not designated as hedges:
Asset derivative instruments:
Current commodity derivatives	Derivative assets, current	$	153		$	464		Derivative assets, current	$	126		$	464
Noncurrent commodity derivatives	Other assets, non-current		111			337		Other assets, non-current		18			337
Liability derivative instruments:
Current commodity derivatives	Derivative liabilities, current		(1,186	)		(4,897	)	Derivative liabilities, current		(2,336	)		(4,897	)
Noncurrent commodity derivatives	Other deferred credits and other liabilities		(20	)		(18	)	Other deferred credits and other liabilities		2			(18	)
Total derivatives not designated as hedges		$	(942	)	$	(4,114	)		$	(2,190	)	$	(4,114	)

Derivatives Designated as Hedge Instruments

The impacts of cash flow hedges on our Consolidated Statements of Comprehensive Income and Consolidated Statements of Income are presented below for the three and nine months ended ~~March 31,~~September 30, 2023 and 2022. Note that this presentation does not reflect the gains or losses arising from the underlying physical transactions; therefore, it is not indicative of the economic profit or loss we realized when the underlying physical and financial transactions were settled.


	Three Months Ended March 31,						Three Months Ended March 31,						Three Months Ended September 30,						Three Months Ended September 30,
	2023		2022				2023			2022			2023			2022			2023			2022
Derivatives in Cash Flow Hedging Relationships	Amount of Gain/(Loss) Recognized in OCI					Location on the Consolidated Statements of Income	Amount of Gain/(Loss) Reclassified from AOCI into Income						Amount of Gain/(Loss) Recognized in OCI					Income Statement Location	Amount of Gain/(Loss) Reclassified from AOCI into Income
	(in thousands)						(in thousands)						(in thousands)						(in thousands)
Interest rate swaps	$	713	$	713		Interest expense	$	(713	)	$	(713	)	$	712		$	712	Interest expense	$	(712	)	$	(712	)
Commodity derivatives		827		(867	)	Fuel, purchased power and cost of natural gas sold		(1,950	)		2,254			(219	)		2,292	Fuel, purchased power and cost of natural gas sold		(34	)		43
Total	$	1,540	$	(154	)		$	(2,663	)	$	1,541		$	493		$	3,004		$	(746	)	$	(669	)


	Nine Months Ended September 30,						Nine Months Ended September 30,
	2023		2022				2023			2022
Derivatives in Cash Flow Hedging Relationships	Amount of Gain/(Loss) Recognized in OCI					Income Statement Location	Amount of Gain/(Loss) Reclassified from AOCI into Income
	(in thousands)						(in thousands)
Interest rate swaps	$	2,138	$	2,138		Interest expense	$	(2,138	)	$	(2,138	)
Commodity derivatives		1,244		(2,946	)	Fuel, purchased power and cost of natural gas sold		(2,473	)		3,620
Total	$	3,382	$	(808	)		$	(4,611	)	$	1,482

As of ~~March 31,~~September 30, 2023, $~~3.6~~3.2 million of net losses related to our interest rate swaps and commodity derivatives are expected to be reclassified from AOCI into earnings within the next 12 months. As market prices fluctuate, estimated and actual realized gains or losses will change during future periods.

1921

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Derivatives Not Designated as Hedge Instruments

The following table summarizes the impacts of derivative instruments not designated as hedge instruments on our Consolidated Statements of Income for the three and nine months ended ~~March 31,~~September 30, 2023 and 2022. Note that this presentation does not reflect the expected gains or losses arising from the underlying physical transactions; therefore, it is not indicative of the economic profit or loss we realized when the underlying physical and financial transactions were settled.


		Three Months Ended March 31,						Three Months Ended September 30,
		2023			2022			2023		2022
Derivatives Not Designated as Hedging Instruments	Location of Gain/(Loss) on Derivatives Recognized in Income	Amount of Gain/(Loss) on Derivatives Recognized in Income					Location of Gain/(Loss) on Derivatives Recognized in Income	Amount of Gain/(Loss) on Derivatives Recognized in Income
Commodity derivatives - Natural Gas	Fuel, purchased power and cost of natural gas sold	$	(3,094	)	$	3,494
		$	(3,094	)	$	3,494		(in thousands)
Commodity derivatives							Fuel, purchased power and cost of natural gas sold	$	255	$	1,617
								$	255	$	1,617


		Nine Months Ended September 30,
		2023			2022
Derivatives Not Designated as Hedging Instruments	Location of Gain/(Loss) on Derivatives Recognized in Income	Amount of Gain/(Loss) on Derivatives Recognized in Income
		(in thousands)
Commodity derivatives	Fuel, purchased power and cost of natural gas sold	$	(2,445	)	$	2,779
		$	(2,445	)	$	2,779

As discussed above, financial instruments used in our regulated Gas Utilities are not designated as cash flow hedges. However, there is no earnings impact because the unrealized gains and losses arising from the use of these financial instruments are recorded as Regulatory assets or Regulatory liabilities. The net unrealized ~~gains~~losses included in our Regulatory ~~liability~~asset accounts related to these financial instruments in our Gas Utilities were $~~0.1~~3.8 million ~~as of March 31, 2023. The net unrealized losses included in our Regulatory asset accounts related to these financial instruments were~~and $8.8 million as of as of September 30, 2023 and December 31, ~~2022. For our Electric Utilities, the unrealized gains and losses arising from these derivatives are recognized in the Consolidated Statements of Income.~~2022, respectively.

(8)

Fair Value Measurements

We use the following fair value hierarchy for determining inputs for our financial instruments. Our assets and liabilities for financial instruments are classified and disclosed in one of the following fair value categories:

Level 1 — Unadjusted quoted prices available in active markets that are accessible at the measurement date for identical unrestricted assets or liabilities. Level 1 instruments primarily consist of highly liquid and actively traded financial instruments with quoted pricing information on an ongoing basis.

Level 2 — Pricing inputs include quoted prices for identical or similar assets and liabilities in active markets other than quoted prices in Level 1, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 3 — Pricing inputs are generally less observable from objective sources. These inputs reflect management’s best estimate of fair value using its own assumptions about the assumptions a market participant would use in pricing the asset or liability.

Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement within the fair value hierarchy levels. We record transfers, if necessary, between levels at the end of the reporting period for all of our financial instruments.

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

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Recurring Fair Value Measurements

Derivatives

The commodity contracts for our Utilities segments are valued using the market approach and include forward strip pricing at liquid delivery points, exchange-traded futures, options, basis swaps and over-the-counter swaps and options (Level 2) for wholesale electric energy and natural gas contracts. For exchange-traded futures, options and basis swap assets and liabilities, fair value was derived using broker quotes validated by the exchange settlement pricing for the applicable contract. For over-the-counter instruments, the fair value is obtained by utilizing a nationally recognized service that obtains observable inputs to compute the fair value, which we validate by comparing our valuation with the counterparty. The fair value of these swaps includes a credit valuation adjustment based on the credit spreads of the counterparties when we are in an unrealized gain position or on our own credit spread when we are in an unrealized loss position. For additional information, see Note 1 of our Notes to the Consolidated Financial Statements in our 2022 Annual Report on Form 10-K.

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The following tables set forth, by level within the fair value hierarchy, our gross assets and gross liabilities and related offsetting of cash collateral and contractual netting rights as permitted by GAAP that were accounted for at fair value on a recurring basis for derivative instruments.


	As of March 31, 2023										As of September 30, 2023
	Level 1		Level 2		Level 3		Cash Collateral and Counterparty Netting (a)		Total		Level 1		Level 2		Level 3		Cash Collateral and Counterparty Netting (a)			Total
	(in thousands)										(in thousands)
Assets:
Commodity derivatives - Gas Utilities	$	-	$	264	$	-	$	-	$	264	$	-	$	5,183	$	-	$	(5,057	)	$	126
Total	$	-	$	264	$	-	$	-	$	264	$	-	$	5,183	$	-	$	(5,057	)	$	126

Liabilities:
Commodity derivatives - Gas Utilities	$	-	$	1,751	$	-	$	-	$	1,751	$	-	$	4,809	$	-	$	(2,598	)	$	2,211
Total	$	-	$	1,751	$	-	$	-	$	1,751	$	-	$	4,809	$	-	$	(2,598	)	$	2,211

(a)

As of ~~March 31,~~September 30, 2023, ~~we had no~~$5.1 million of our commodity derivative assets orand $2.6 million of our commodity derivative liabilities, oras well as related gross collateral amounts, ~~that~~ were subject to master netting agreements.


	As of December 31, 2022
	Level 1		Level 2		Level 3		Cash Collateral and Counterparty Netting (a)			Total
	(in thousands)
Assets:
Commodity derivatives - Gas Utilities	$	-	$	5,407	$	-	$	(4,290	)	$	1,117
Total	$	-	$	5,407	$	-	$	(4,290	)	$	1,117

Liabilities:
Commodity derivatives - Gas Utilities	$	-	$	11,455	$	-	$	(4,837	)	$	6,618
Total	$	-	$	11,455	$	-	$	(4,837	)	$	6,618

(a)

As of December 31, 2022, $4.3 million of our commodity derivative assets and $4.8 million of our commodity derivative liabilities, as well as related gross collateral amounts, were subject to master netting agreements.

Pension and Postretirement Plan Assets

Fair value measurements also apply to the valuation of our pension and postretirement plan assets. Current accounting guidance requires employers to annually disclose information about the fair value measurements of their assets of a defined benefit pension or other postretirement plan. The fair value of these assets is presented in Note 13 to the Consolidated Financial Statements included in our 2022 Annual Report on Form 10-K.

Other Fair Value Measures

The carrying amount of cash and cash equivalents, restricted cash and equivalents and short-term borrowings approximates fair value due to their liquid or short-term nature. Cash, cash equivalents and restricted cash are classified in Level 1 in the fair value hierarchy. Notes payable consist of commercial paper borrowings and are not traded on an exchange; therefore, they are classified as Level 2 in the fair value hierarchy.

Table of Contents

The following table presents the carrying amounts and fair values of financial instruments not recorded at fair value on the Consolidated Balance Sheets (in thousands) as of:

March 31, 2023

December 31, 2022

Carrying Amount

Fair Value

Carrying Amount

Fair Value

Long-term debt, including current maturities (a)
$
4,479,409

$
4,205,369

$
4,132,340

$
3,760,848


	September 30, 2023				December 31, 2022
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current maturities (a)	$	4,924,510	$	4,481,989	$	4,132,340	$	3,760,848

(a)

Long-term debt is valued based on observable inputs available either directly or indirectly for similar liabilities in active markets and therefore is classified in Level 2 in the fair value hierarchy. Carrying amount of long-term debt is net of deferred financing costs.

~~Table of Contents~~

(9)

Other Comprehensive Income

We record deferred gains (losses) in AOCI related to interest rate swaps designated as cash flow hedges, commodity contracts designated as cash flow hedges and the amortization of components of our defined benefit plans. Deferred gains (losses) for our commodity contracts designated as cash flow hedges are recognized in earnings upon settlement, while deferred gains (losses) related to our interest rate swaps are recognized in earnings as they are amortized.

The following table details reclassifications out of AOCI and into Net income. The amounts in parentheses below indicate decreases to Net income in the Consolidated Statements of Income for the period, net of tax (in thousands):


		Amount Reclassified from AOCI							Amount Reclassified from AOCI						Amount Reclassified from AOCI
	Location on the Consolidated Statements of Income	Three Months Ended March 31,						Location on the Consolidated Statements of Income	Three Months Ended September 30,						Nine Months Ended September 30,
		2023			2022				2023			2022			2023			2022
Gains and (losses) on cash flow hedges:
Interest rate swaps	Interest expense	$	(713	)	$	(713	)	Interest expense	$	(712	)	$	(712	)	$	(2,138	)	$	(2,138	)
Commodity contracts	Fuel, purchased power and cost of natural gas sold		(1,950	)		2,254		Fuel, purchased power and cost of natural gas sold		(34	)		43			(2,473	)		3,620
		$	(2,663	)	$	1,541			$	(746	)	$	(669	)	$	(4,611	)	$	1,482
Income tax	Income tax expense		616			(375	)	Income tax expense		170			124			1,081			(332	)
Total reclassification adjustments related to cash flow hedges, net of tax		$	(2,047	)	$	1,166			$	(576	)	$	(545	)	$	(3,530	)	$	1,150

Amortization of components of defined benefit plans:
Prior service cost	Operations and maintenance	$	-		$	24		Operations and maintenance	$	-		$	24		$	-		$	70
Actuarial gain (loss)	Operations and maintenance		(44	)		(188	)	Operations and maintenance		(43	)		(188	)		(129	)		(563	)
		$	(44	)	$	(164	)		$	(43	)	$	(164	)	$	(129	)	$	(493	)
Income tax	Income tax expense		16			39		Income tax expense		19			58			62			157
Total reclassification adjustments related to defined benefit plans, net of tax		$	(28	)	$	(125	)		$	(24	)	$	(106	)	$	(67	)	$	(336	)
Total reclassifications		$	(2,075	)	$	1,041			$	(600	)	$	(651	)	$	(3,597	)	$	814

Balances by classification included within AOCI, net of tax on the accompanying Consolidated Balance Sheets were as follows (in thousands):

Derivatives Designated as Cash Flow Hedges

Interest Rate Swaps

Commodity Derivatives

Employee Benefit Plans

Total

As of December 31, 2022
$
(8,255
)
$
(1,200
)
$
(6,112
)
$
(15,567
)
Other comprehensive income (loss)

before reclassifications

-

(855
)

-

(855
)
Amounts reclassified from AOCI

563

1,484

28

2,075

As of March 31, 2023
$
(7,692
)
$
(571
)
$
(6,084
)
$
(14,347
)

Derivatives Designated as Cash Flow Hedges

Interest Rate Swaps

Commodity Derivatives

Employee Benefit Plans

Total

As of December 31, 2021
$
(10,384
)
$
1,476

$
(11,176
)
$
(20,084
)
Other comprehensive income (loss)

before reclassifications

-

1,047

-

1,047

Amounts reclassified from AOCI

536

(1,702
)

125

(1,041
)
As of March 31, 2022
$
(9,848
)
$
821

$
(11,051
)
$
(20,078
)


	Derivatives Designated as Cash Flow Hedges
	Interest Rate Swaps			Commodity Derivatives			Employee Benefit Plans			Total
As of December 31, 2022	$	(8,255	)	$	(1,200	)	$	(6,112	)	$	(15,567	)
Other comprehensive income (loss)
before reclassifications		-			(937	)		-			(937	)
Amounts reclassified from AOCI		1,649			1,881			67			3,597
As of September 30, 2023	$	(6,606	)	$	(256	)	$	(6,045	)	$	(12,907	)

2224

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	Derivatives Designated as Cash Flow Hedges
	Interest Rate Swaps			Commodity Derivatives			Employee Benefit Plans			Total
As of December 31, 2021	$	(10,384	)	$	1,476		$	(11,176	)	$	(20,084	)
Other comprehensive income (loss)
before reclassifications		-			509			-			509
Amounts reclassified from AOCI		1,589			(2,739	)		336			(814	)
As of September 30, 2022	$	(8,795	)	$	(754	)	$	(10,840	)	$	(20,389	)

(10)

Employee Benefit Plans

Components of Net Periodic Expense

The components of net periodic expense were as follows (in thousands):


	Defined Benefit Pension Plan						Supplemental Non-qualified Defined Benefit Plans					Non-pension Defined Benefit Postretirement Healthcare Plan						Defined Benefit Pension Plan						Supplemental Non-qualified Defined Benefit Plans						Non-pension Defined Benefit Postretirement Healthcare Plan
Three Months Ended March 31,	2023			2022			2023		2022			2023			2022
Three Months Ended September 30,																		2023			2022			2023			2022			2023			2022
Service cost	$	614		$	982		$	914	$	(392	)	$	381		$	492		$	614		$	982		$	(77	)	$	(271	)	$	381		$	492
Interest cost		4,381			2,705			369		208			594			321			4,381			2,705			369			209			594			321
Expected return on plan assets		(4,672	)		(4,631	)		-		-			(56	)		(31	)		(4,672	)		(4,631	)		-			-			(55	)		(31	)
Net amortization of prior service costs		(17	)		(17	)		-		-			10			(72	)		(17	)		(17	)		-			-			10			(72	)
Recognized net actuarial loss (gain)		498			1,523			8		69			(3	)		16
Recognized net actuarial loss																			498			1,522			8			69			(3	)		16
Net periodic expense (benefit)	$	804		$	562		$	1,291	$	(115	)	$	926		$	726		$	804		$	561		$	300		$	7		$	927		$	726


	Defined Benefit Pension Plan						Supplemental Non-qualified Defined Benefit Plans					Non-pension Defined Benefit Postretirement Healthcare Plan
Nine Months Ended September 30,	2023			2022			2023		2022			2023			2022
Service cost	$	1,842		$	2,946		$	1,607	$	(2,018	)	$	1,143		$	1,476
Interest cost		13,142			8,114			1,107		626			1,783			963
Expected return on plan assets		(14,016	)		(13,892	)		-		-			(167	)		(93	)
Net amortization of prior service costs		(51	)		(51	)		-		-			30			(217	)
Recognized net actuarial loss (gain)		1,494			4,568			24		207			(9	)		48
Net periodic expense (benefit)	$	2,411		$	1,685		$	2,738	$	(1,185	)	$	2,780		$	2,177

Plan Contributions

Contributions to the Defined Benefit Pension Plan are cash contributions made directly to the Pension Plan Trust account. Contributions to the Postretirement Healthcare and Supplemental Plans are primarily made in the form of benefit payments. Contributions made in the first ~~three~~nine months of 2023 and anticipated contributions for 2023 and 2024 are as follows (in thousands):


	Contributions Made		Additional Contributions		Contributions		Contributions Made		Additional Contributions		Contributions
	Three Months Ended March 31, 2023		Anticipated for 2023		Anticipated for 2024		Nine Months Ended September 30, 2023		Anticipated for 2023		Anticipated for 2024
Defined Benefit Pension Plan	$	-	$	-	$	-	$	-	$	-	$	-
Non-pension Defined Benefit Postretirement Healthcare Plan	$	1,230	$	3,690	$	4,556	$	3,690	$	1,230	$	4,808
Supplemental Non-qualified Defined Benefit and Defined Contribution Plans	$	558	$	1,673	$	2,410	$	1,673	$	558	$	2,417

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Income Taxes

IRS Revenue Procedure 2023-15

On April 14, 2023, the IRS released Revenue Procedure 2023-15 “Amounts paid to improve tangible property.” The Revenue Procedure provides a safe harbor method of accounting that taxpayers may use to determine whether ~~expenses~~costs to repair, maintain, replace, or improve natural gas transmission and distribution property must be capitalized. We are currently assessing the Revenue Procedure to determine its impact on our tax repairs deduction.

Income Tax ~~Expense~~Benefit (Expense) and Effective Tax Rates

Three Months Ended ~~March 31,~~September 30, 2023 Compared to the Three Months Ended ~~March 31,~~September 30, 2022

Income tax ~~expense~~(expense) for the three months ended ~~March 31,~~September 30, 2023 was $$(~~14.7~~7.4) million compared to $$(~~14.5~~2.1) million reported for the same period in 2022. For the three months ended ~~March 31,~~September 30, 2023, the effective tax rate was ~~11.1~~13.1% ~~which was comparable~~compared to ~~10.7~~5.2% for the same period in 2022. The higher effective tax rate was primarily due to $1.4 million of lower tax benefits from various current and prior year state rate changes.

23Nine Months Ended September 30, 2023 Compared to the Nine Months Ended September 30, 2022

~~Table of Contents~~

Income tax (expense) for the nine months ended September 30, 2023 was $(16.0) million compared to $(15.9) million reported for the same period in 2022. For the nine months ended September 30, 2023, the effective tax rate was 7.6% compared to 7.6% for the same period in 2022. The effective tax rate was comparable primarily due to a $8.2 million tax benefit from a current year Nebraska income tax rate decrease offset by $5.8 million of lower tax benefits from various current and prior year state tax rate changes and $2.3 million of lower wind PTCs driven by the March 2023 sale of Northern Iowa Windpower assets.

(12)

Business Segment Information

Our Chief Executive Officer, who is considered to be our CODM, reviews financial information presented on an operating segment basis for purposes of making decisions, allocating resources and assessing financial performance. Our CODM assesses the performance of our operating segments based on operating income.

Segment information was as follows (in thousands):

Total assets (net of intercompany eliminations) as of:
March 31, 2023

December 31, 2022

Electric Utilities
$
3,922,496

$
3,929,721

Gas Utilities

5,419,216

5,578,282

Corporate and Other

118,424

110,227

Total assets
$
9,460,136

$
9,618,230

External Operating Revenue

Inter-company Operating Revenue

Three Months Ended March 31, 2023
Contract Customers

Other Revenues

Contract Customers

Other Revenues

Total Revenues

Segment:

Electric Utilities
$
215,012

$
881

$
2,816

$
-

$
218,709

Gas Utilities

697,043

8,223

1,650

-

706,916

Inter-company eliminations

-

-

(4,466
)

-

(4,466
)
Total
$
912,055

$
9,104

$
-

$
-

$
921,159

External Operating Revenue

Inter-company Operating Revenue

Three Months Ended March 31, 2022
Contract Customers

Other Revenues

Contract Customers

Other Revenues

Total Revenues

Segment:

Electric Utilities
$
202,739

$
870

$
2,929

$
-

$
206,538

Gas Utilities

619,030

931

1,319

112

621,392

Inter-company eliminations

-

-

(4,248
)

(112
)

(4,360
)
Total
$
821,769

$
1,801

$
-

$
-

$
823,570

Three Months Ended March 31,

2023

2022

Operating income (loss):

Electric Utilities
$
61,060

$
50,746

Gas Utilities

114,625

123,540

Corporate and Other

(802
)

(933
)
Operating income

174,883

173,353

Interest expense, net

(43,504
)

(38,545
)
Other income, net

674

704

Income tax expense

(14,673
)

(14,488
)
Net income

117,380

121,024

Net income attributable to non-controlling interest

(3,296
)

(3,498
)
Net income available for common stock
$
114,084

$
117,526


	Three Months Ended September 30,						Nine Months Ended September 30,
	2023			2022			2023			2022
Revenues:
Electric Utilities
External Customers	$	234,490		$	255,741		$	640,595		$	660,800
Inter-segment		2,839			2,928			8,516			8,786
Total Electric Utilities Revenue		237,329			258,669			649,111			669,586

Gas Utilities
External Customers		172,636			206,871			1,098,973			1,099,577
Inter-segment		1,649			1,417			4,948			4,272
Total Gas Utilities Revenue		174,285			208,288			1,103,921			1,103,849

Inter-segment eliminations		(4,488	)		(4,345	)		(13,464	)		(13,058	)

Total Revenues	$	407,126		$	462,612		$	1,739,568		$	1,760,377

Operating income (loss):
Electric Utilities	$	83,016		$	69,483		$	190,695		$	165,455
Gas Utilities		15,400			10,583			147,750			162,318
Corporate and Other		(645	)		(587	)		(2,275	)		(2,552	)
Total Operating Income	$	97,771		$	79,479		$	336,170		$	325,221

2426

Table of Contents


Total assets (net of inter-segment eliminations) as of:	September 30, 2023		December 31, 2022
Electric Utilities	$	3,938,835	$	3,929,721
Gas Utilities		5,301,383		5,578,282
Corporate and Other		692,710		110,227
Total assets	$	9,932,928	$	9,618,230

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Selected Balance Sheet Information

Accounts Receivable and Allowance for Credit Losses

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


	March 31, 2023			December 31, 2022			September 30, 2023			December 31, 2022
Billed Accounts Receivable	$	327,949		$	267,571		$	164,171		$	267,571
Unbilled Revenue		154,571			243,574			66,478			243,574
Less: Allowance for Credit Losses		(5,431	)		(2,953	)		(1,819	)		(2,953	)
Account Receivable, net	$	477,089		$	508,192		$	228,830		$	508,192

Changes to allowance for credit losses for the ~~three~~nine months ended ~~March 31,~~September 30, 2023 and 2022, respectively, were as follows (in thousands):


	Balance at Beginning of Year		Additions Charged to Costs and Expenses		Recoveries and Other Additions		Write-offs and Other Deductions			Balance at March 31,		Balance at Beginning of Year		Additions Charged to Costs and Expenses		Recoveries and Other Additions		Write-offs and Other Deductions			Balance at September 30,
2023	$	2,953	$	3,703	$	641	$	(1,866	)	$	5,431	$	2,953	$	7,195	$	2,445	$	(10,774	)	$	1,819
2022	$	2,113	$	3,416	$	655	$	(1,698	)	$	4,486	$	2,113	$	6,473	$	2,117	$	(8,768	)	$	1,935

Materials, Supplies and Fuel

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


	March 31, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Materials and supplies	$	102,328	$	99,734	$	104,945	$	99,734
Fuel - Electric Utilities		6,808		3,115		7,674		3,115
Natural gas in storage		20,824		104,572		55,460		104,572
Total materials, supplies and fuel	$	129,960	$	207,421	$	168,079	$	207,421

Accrued Liabilities

The following amounts by major classification are included in Accrued liabilities on the accompanying Consolidated Balance Sheets (in thousands) as of:


	March 31, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Accrued employee compensation, benefits and withholdings	$	48,555	$	62,890	$	65,620	$	62,890
Accrued property taxes		54,694		52,430		46,309		52,430
Customer deposits and prepayments		42,124		47,655		57,100		47,655
Accrued interest		47,928		33,798		49,314		33,798
Other (none of which is individually significant)		35,560		46,684		39,115		46,684
Total accrued liabilities	$	228,861	$	243,457	$	257,458	$	243,457

(14)

Subsequent Events

Except as described in ~~Notes~~ Notes 2 and 113, there have been no events subsequent to ~~March 31,~~September 30, 2023, which would require recognition in the ~~consolidated financial statements~~Consolidated Financial Statements or disclosures.

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

The following discussions should be read in conjunction with the Notes contained herein and Management's Discussion and Analysis of Financial Condition and Results of Operations appearing in the 2022 Form 10-K.

Executive Summary

We are a customer-focused energy solutions provider with a mission of Improving Life with Energy for more than 1.3 million customers and 800+ communities we serve. Our vision to be the Energy Partner of Choice directs our strategy to invest in the safety, sustainability and growth of our eight-state service territory, including Arkansas, Colorado, Iowa, Kansas, Montana, Nebraska, South Dakota and Wyoming, and to meet our essential objective of providing safe, reliable and cost-effective electricity and natural gas.

We conduct our business operations through two operating segments: Electric Utilities and Gas Utilities. Certain unallocated corporate expenses that support our operating segments are presented as Corporate and Other. We conduct our utility operations under the name Black Hills Energy predominantly in rural areas of the Rocky Mountains and Midwestern states. We consider ourself a domestic electric and natural gas utility company.

We have provided energy and served customers for 139 years, since the 1883 gold rush days in Deadwood, South Dakota. Throughout our history, the common thread that unites the past to the present is our commitment to serve our customers and communities. By being responsive and service focused, we can help our customers and communities thrive while meeting rapidly changing customer expectations.

Recent Developments

Business Segment Recent Developments

Electric Utilities

•

See Note 2 of the Condensed Notes to Consolidated Financial Statements for recent rate review activity for Wyoming Electric.

•

On July 31, 2023, Colorado Electric issued a request for proposals for 400 MW of new resources to be in service between 2026 and 2029 to achieve objectives in its Clean Energy Plan. In March 2023, the CPUC approved a unanimous settlement for Colorado Electric's Clean Energy Plan filed May 25, 2022. The Clean Energy Plan ~~is expected to add approximately 400 MW of new clean energy resources needed~~supports Colorado Electric's voluntary election to reduce carbon emissions 80% from 2005 levels by 2030. Final bids were due in October 2023, and we received a diverse project proposal response. We are evaluating bids and expect a publicly available bid summary in the 30-day report on November 19, 2023, and will select finalists as part of a 120-day report to be submitted to the CPUC during the first quarter of 2024.

•

On July 24, 2023, Wyoming Electric set a new all-time and summer peak load of 312 MW, surpassing the previous peak of 294 MW set on July 21, 2022.

Gas Utilities

•

See Note 2 of the Condensed Notes to Consolidated Financial Statements for recent rate review activity for ~~RMNG.~~Colorado Gas, RMNG and Wyoming Gas.

Corporate and Other

•

~~On March 7, 2023, we completed a public debt offering~~See Note 3 of ~~$350 million, 5.95% 5-year senior unsecured notes due March 15, 2028. The proceeds from~~ the ~~offering were used~~Condensed Notes to ~~repay notes outstanding under our commercial paper program and~~Consolidated Financial Statements for ~~other general corporate purposes.~~ recent updates regarding the GT Resources, LLC v. Black Hills Corporation lawsuit.

•

See Note 5 of the Condensed Notes to Consolidated Financial Statements for ~~further information.~~information regarding our March 7, 2023 and September 15, 2023 debt offerings.

•

See Note 5 of the Condensed Notes to Consolidated Financial Statements for information regarding our new shelf registration with the SEC and our new Equity Distribution Sales Agreement.

Table of Contents

Results of Operations

Certain lines of business in which we operate are highly seasonal, and revenue from, and certain expenses for, such operations may fluctuate significantly among quarterly periods. Demand for electricity and natural gas is sensitive to seasonal cooling, heating and industrial load requirements. In particular, the normal peak usage season for our Electric Utilities is June through August while the normal peak usage season for our Gas Utilities is November through March. Significant earnings variances can be expected between the Gas Utilities segment’s peak and off-peak seasons. Due to this seasonal nature, our results of operations for the three and nine months ended ~~March 31,~~September 30, 2023 and 2022, and our financial condition as of ~~March 31,~~September 30, 2023 and December 31, 2022, are not necessarily indicative of the results of operations and financial condition to be expected as of or for any other period or for the entire year.

Segment information does not include ~~inter-company~~inter-segment eliminations and all amounts are presented on a pre-tax basis unless otherwise indicated. Minor differences in amounts may result due to rounding.

~~Table of Contents~~

Consolidated Summary and Overview


	Three Months Ended March 31,						Three Months Ended September 30,						Nine Months Ended September 30,
	2023			2022			2023			2022			2023			2022
	(in thousands, except per share amounts)						(in thousands, except per share amounts)
Operating income (loss):
Electric Utilities	$	61,060		$	50,746		$	83,016		$	69,483		$	190,695		$	165,455
Gas Utilities		114,625			123,540			15,400			10,583			147,750			162,318
Corporate and Other		(802	)		(933	)		(645	)		(587	)		(2,275	)		(2,552	)
Operating income		174,883			173,353			97,771			79,479			336,170			325,221

Interest expense, net		(43,504	)		(38,545	)		(40,998	)		(40,019	)		(126,023	)		(117,328	)
Other income, net		674			704
Other income (expense), net								(647	)		464			(1,513	)		2,731
Income tax (expense)		(14,673	)		(14,488	)		(7,366	)		(2,090	)		(15,950	)		(15,920	)
Net income		117,380			121,024			48,760			37,834			192,684			194,704
Net income attributable to non-controlling interest		(3,296	)		(3,498	)		(3,377	)		(2,861	)		(10,164	)		(8,790	)
Net income available for common stock	$	114,084		$	117,526		$	45,383		$	34,973		$	182,520		$	185,914

Total earnings per share of common stock, Diluted	$	1.73		$	1.82		$	0.67		$	0.54		$	2.74		$	2.86

Three Months Ended ~~March 31,~~September 30, 2023 Compared to the Three Months Ended ~~March 31,~~September 30, 2022:

The variance to the prior year included the following:

•

Electric Utilities' operating income increased $13.5 million primarily due to a one-time recovery from our business interruption insurance related to the 2021 Wygen I unplanned outage, a gain on a strategic sale of land in Wyoming to a customer to support continued load growth, and new rates and rider recovery, partially offset by unfavorable weather;

•

Gas Utilities' operating income increased $4.8 million primarily due to new rates and rider recovery and lower operating expenses;

•

Income tax expense increased $5.3 million driven by higher pre-tax income and an effective tax rate of 13.1% compared to 5.2% for the same period in 2022. The higher effective tax rate was primarily due to decreased tax benefits from various current and prior year state rate changes.

Nine Months Ended September 30, 2023 Compared to the Nine Months Ended September 30, 2022:

The variance to the prior year included the following:

•

Electric Utilities’ operating income increased ~~$10~~$25.2 million primarily due to new rates and rider recovery, increased transmission services revenue and off-system excess energy sales, a one-time gain on the planned sale of Northern Iowa Windpower assets, ~~new rates~~a gain on a strategic sale of land in Wyoming to a customer to support continued load growth, and ~~rider~~a one-time recovery ~~and increased transmission services and off-system excess energy sales~~from our business interruption insurance related to the 2021 Wygen I unplanned outage partially offset by higher ~~generation-related~~employee-related expenses and ~~employee costs;~~unfavorable weather;

Table of Contents

•

Gas Utilities’ operating income decreased ~~$8.9~~$14.6 million primarily due to higher ~~operating~~employee-related expenses, a prior year one-time true-up of carrying costs accrued on Winter Storm Uri regulatory assets and unfavorable mark-to-market adjustments on wholesale commodity contracts partially offset by new rates and rider recovery and retail customer growth and ~~demand.~~demand;

•

Interest expense, net increased ~~$5.0~~$8.7 million due to higher interest ~~rates;~~rates partially offset by increased interest income on higher cash and cash equivalents balances; and

•

Other expense, net increased $4.2 million primarily due to higher non-service benefit plan costs driven by higher discount rates and higher costs for our non-qualified benefit plans driven by market performance.

Segment Operating Results

A discussion of operating results from our business segments follows.

Non-GAAP Financial Measures

The following discussion includes financial information prepared in accordance with GAAP, as well as another financial measure, Electric and Gas Utility 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. Electric and Gas Utility margin (revenue less cost of sales) is a non-GAAP financial measure due to the exclusion of operation and maintenance expenses, depreciation and amortization expenses, and property and production taxes from the measure.

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

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

~~Table of Contents~~

Electric Utilities

Operating results for the Electric Utilities were as follows (in thousands):


	Three Months Ended March 31,							Three Months Ended September 30,							Nine Months Ended September 30,
	2023		2022		Variance			2023		2022		Variance			2023		2022		Variance
Revenue:
Electric - regulated	$	206,702	$	195,725	$	10,977		$	221,715	$	245,269	$	(23,554	)	$	611,238	$	635,190	$	(23,952	)
Other - non-regulated		12,007		10,813		1,194			15,614		13,401		2,213			37,873		34,396		3,477
Total revenue		218,709		206,538		12,171			237,329		258,669		(21,340	)		649,111		669,586		(20,475	)

Cost of fuel and purchased power:
Electric - regulated		54,650		51,479		3,171			54,974		84,309		(29,335	)		145,662		191,511		(45,849	)
Other - non-regulated		766		931		(165	)		454		1,644		(1,190	)		1,586		3,484		(1,898	)
Total cost of fuel and purchased power		55,416		52,410		3,006			55,428		85,953		(30,525	)		147,248		194,995		(47,747	)

Electric Utility margin (non-GAAP)		163,293		154,128		9,165			181,901		172,716		9,185			501,863		474,591		27,272

Operations and maintenance		67,154		69,669		(2,515	)		63,114		68,896		(5,782	)		204,487		207,565		(3,078	)
Depreciation and amortization		35,079		33,713		1,366			35,771		34,337		1,434			106,681		101,571		5,110
Total operating expenses		102,233		103,382		(1,149	)
									98,885		103,233		(4,348	)		311,168		309,136		2,032

Operating income	$	61,060	$	50,746	$	10,314		$	83,016	$	69,483	$	13,533		$	190,695	$	165,455	$	25,240

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Three Months Ended ~~March 31,~~September 30, 2023, Compared to the Three Months Ended ~~March 31,~~September 30, 2022:

Electric Utility margin increased as a result of the following:


	(in millions)			(in millions)
New rates and rider recovery	$	4.6		$	5.7
Transmission services and off-system excess energy sales		2.9
Integrated Generation (a)		2.1
Wygen I revenue recovery under business interruption insurance (a)					5.0
Weather					(2.3	)
Other		(0.4	)		0.8
	$	9.2		$	9.2

(a)

In 2021, Wygen I experienced an unplanned outage which resulted in lost revenue. A claim for these losses was submitted under our business interruption insurance policy. During the third quarter of 2023, we recovered $5.0 million from our business interruption insurance which was recognized as Revenue. See Note 3 of the Condensed Notes to Consolidated Financial Statements for further information.

Operations and maintenance expense decreased primarily due to a $3.9 million gain on a strategic sale of land in Wyoming to a customer to support continued load growth.

Depreciation and amortization increased primarily due to a higher asset base driven by current year and prior year capital expenditures.

Nine Months Ended September 30, 2023, Compared to the Nine Months Ended September 30, 2022:

Electric Utility margin increased as a result of the following:


	(in millions)
New rates and rider recovery	$	15.9
Wygen I revenue recovery under business interruption insurance (a)		5.0
Integrated Generation (b)		5.0
Transmission services		2.8
Off-system excess energy sales		1.1
Weather		(4.5	)
Other		2.0
	$	27.3

(a)

(b)

Primarily driven by favorable mining volumes due to a prior year planned outage, mining contract ~~pricing.~~pricing and increased Black Hills Colorado IPP fired-engine hours.

Operations and maintenance expense decreased primarily due to a one-time $7.7 million gain on the planned sale of Northern Iowa Windpower assets and a $3.9 million gain on a strategic sale of land in Wyoming to a customer to support continued load growth partially offset by ~~$2.9~~$5.5 million of higher employee-related expenses and ~~$2.9~~$3.5 million of higher ~~Integrated Generation~~mining and generation expenses driven by a planned ~~outage~~outages, higher fuel costs and higher ~~fuel and~~ materials costs.

Depreciation and amortization increased primarily due to a higher asset base driven by current year and prior year capital expenditures.

2831

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Operating Statistics


	Revenue (in thousands)				Quantities Sold (MWh)				Revenue (in thousands)								Quantities Sold (MWh)
	Three Months Ended March 31,				Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022		2023		2022		2023		2022		2023		2022		2023		2022
Residential	$	59,798	$	62,249		393,870		391,582	$	63,107	$	72,115	$	170,279	$	187,217		393,830		421,782		1,090,579		1,137,139
Commercial		62,072		64,353		510,790		490,418		69,508		77,314		195,110		210,423		567,111		581,239		1,576,141		1,581,487
Industrial		38,948		35,408		455,942		463,768		42,988		47,090		116,455		120,688		553,481		483,223		1,511,569		1,411,919
Municipal		4,267		4,575		35,766		35,305		4,731		6,093		13,202		15,660		42,782		46,745		116,118		122,290
Subtotal Retail Revenue - Electric		165,085		166,585		1,396,368		1,381,073		180,334		202,612		495,046		533,989		1,557,204		1,532,989		4,294,407		4,252,835
Contract Wholesale		5,404		5,923		144,791		182,207		6,839		8,378		15,449		18,639		140,547		160,070		403,682		492,922
Off-system/Power Marketing Wholesale		16,124		7,154		256,856		160,441		9,580		16,769		31,663		32,590		138,438		131,469		518,552		436,335
Other (a)		20,089		16,063		-		-		24,962		17,509		69,080		49,972		-		-		-		-
Total Regulated		206,702		195,725		1,798,015		1,723,721		221,715		245,269		611,238		635,190		1,836,189		1,824,528		5,216,641		5,182,092
Non-Regulated (b)		12,007		10,813		54,346		89,094		15,614		13,401		37,873		34,396		25,369		59,745		102,563		221,609
Total Revenue and Quantities Sold	$	218,709	$	206,538		1,852,361		1,812,815	$	237,329	$	258,669	$	649,111	$	669,586		1,861,558		1,884,273		5,319,204		5,403,701
Other Uses, Losses or Generation, net (c)						138,305		113,286										97,709		125,613		345,642		337,222
Total Energy						1,990,666		1,926,101										1,959,267		2,009,886		5,664,846		5,740,923

(a)

Primarily related to transmission revenues from the Common Use System.

(b)

Includes Integrated Generation and non-regulated services to our retail customers under the Service Guard Comfort Plan and Tech Services.

(c)

Includes company uses and line losses.


	Revenue (in thousands)				Quantities Sold (MWh)				Revenue (in thousands)								Quantities Sold (MWh)
	Three Months Ended March 31,				Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022		2023		2022		2023		2022		2023		2022		2023		2022
Colorado Electric	$	73,795	$	75,445		604,543		619,588	$	80,771	$	96,380	$	216,904	$	243,022		653,166		647,532		1,794,464		1,836,010
South Dakota Electric		86,614		78,597		708,821		644,223		83,024		94,281		240,588		249,073		622,670		684,059		1,876,714		1,928,454
Wyoming Electric		46,671		42,089		484,651		459,910		58,429		55,058		155,039		144,293		560,353		492,938		1,545,463		1,417,629
Integrated Generation		11,629		10,407		54,346		89,094		15,105		12,950		36,580		33,198		25,369		59,744		102,563		221,608
Total Revenue and Quantities Sold	$	218,709	$	206,538		1,852,361		1,812,815	$	237,329	$	258,669	$	649,111	$	669,586		1,861,558		1,884,273		5,319,204		5,403,701

Three Months Ended March 31,

Quantities Generated and Purchased by Fuel Type (MWh)
2023

2022

Generated:

Coal

674,947

663,438

Natural Gas and Oil

501,066

296,422

Wind

230,724

253,568

Total Generated

1,406,737

1,213,428

Purchased:

Coal, Natural Gas, Oil and Other Market Purchases

489,816

588,160

Wind

94,113

124,513

Total Purchased

583,929

712,673

Total Generated and Purchased

1,990,666

1,926,101

Three Months Ended March 31,

Quantities Generated and Purchased (MWh)
2023

2022

Generated:

Colorado Electric

160,201

85,431

South Dakota Electric

564,044

455,605

Wyoming Electric

230,562

204,598

Integrated Generation

451,930

467,794

Total Generated

1,406,737

1,213,428

Purchased:

Colorado Electric

197,624

300,397

South Dakota Electric

156,972

197,063

Wyoming Electric

209,793

190,805

Integrated Generation

19,540

24,408

Total Purchased

583,929

712,673

Total Generated and Purchased

1,990,666

1,926,101


	Three Months Ended September 30,				Nine Months Ended September 30,
Quantities Generated and Purchased by Fuel Type (MWh)	2023		2022		2023		2022
Generated:
Coal		704,227		736,181		2,000,126		1,989,057
Natural Gas and Oil		540,927		457,790		1,493,230		1,016,369
Wind		138,527		143,278		519,873		641,302
Total Generated		1,383,681		1,337,249		4,013,229		3,646,728
Purchased:
Coal, Natural Gas, Oil and Other Market Purchases		459,141		609,699		1,369,994		1,805,904
Wind and Solar		116,445		62,938		281,623		288,291
Total Purchased		575,586		672,637		1,651,617		2,094,195

Total Generated and Purchased		1,959,267		2,009,886		5,664,846		5,740,923

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	Three Months Ended September 30,				Nine Months Ended September 30,
Quantities Generated and Purchased (MWh)	2023		2022		2023		2022
Generated:
Colorado Electric		211,420		127,090		491,995		324,638
South Dakota Electric		489,160		510,443		1,500,696		1,333,984
Wyoming Electric		221,999		236,761		667,730		667,079
Integrated Generation		461,102		462,955		1,352,808		1,321,027
Total Generated		1,383,681		1,337,249		4,013,229		3,646,728
Purchased:
Colorado Electric		116,234		251,076		442,216		807,442
South Dakota Electric		177,341		221,872		438,646		667,560
Wyoming Electric		267,583		174,946		723,542		551,683
Integrated Generation		14,428		24,743		47,213		67,510
Total Purchased		575,586		672,637		1,651,617		2,094,195

Total Generated and Purchased		1,959,267		2,009,886		5,664,846		5,740,923


	Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022		2023		2022
Degree Days	Actual	Variance from Normal	Actual	Variance from Normal	Actual	Variance from Normal	Actual	Variance from Normal	Actual	Variance from Normal	Actual	Variance from Normal
Heating Degree Days:
Colorado Electric	2,751	8%	2,715	8%	26	(42)%	25	(66)%	3,365	5%	3,296	4%
South Dakota Electric	3,446	5%	3,248	(1)%	140	(15)%	91	(57)%	4,621	2%	4,560	---%
Wyoming Electric	3,301	10%	3,132	4%	152	(12)%	119	(60)%	4,534	4%	4,410	(2)%
Combined (a)	3,099	7%	2,981	4%	91	(19)%	66	(60)%	4,031	4%	3,952	1%

Cooling Degree Days:
Colorado Electric					909	6%	1,028	28%	1,040	(10)%	1,361	27%
South Dakota Electric					460	(11)%	707	38%	496	(21)%	814	35%
Wyoming Electric					315	(20)%	580	72%	329	(30)%	701	77%
Combined (a)					635	(2)%	828	36%	710	(15)%	1,041	34%

(a)

Degree days are calculated based on a weighted average of total customers by state.


	Three Months Ended March 31,		Three Months Ended September 30,		Nine Months Ended September 30,
Contracted generating facilities Availability by fuel type (a)	2023	2022
Contracted generating facilities availability by fuel type (a)			2023	2022	2023	2022
Coal(b)	92.7%	90.6%	96.3%	96.5%	93.7%	89.7%
Natural gas and diesel oil	94.3%	95.3%	94.2%	97.0%	94.0%	95.8%
Wind	92.5%	95.6%	93.4%	94.4%	93.4%	94.6%
Total Availability	93.6%	94.1%	94.7%	96.4%	93.8%	94.0%

Wind Capacity Factor	48.1%	42.0%	31.3%	22.9%	37.9%	34.7%

(a)

Availability and Wind Capacity Factor are calculated using a weighted average based on capacity of our generating fleet.

(b)

2022 included planned outages at Neil Simpson II and Wyodak Plant.

Table of Contents

Gas Utilities

Operating results for the Gas Utilities were as follows (in thousands):


	Three Months Ended March 31,							Three Months Ended September 30,							Nine Months Ended September 30,
	2023		2022		Variance			2023		2022		Variance			2023		2022		Variance
Revenue:
Natural gas - regulated	$	674,773	$	596,458	$	78,315		$	159,481	$	192,104	$	(32,623	)	$	1,041,017	$	1,046,910	$	(5,893	)
Other - non-regulated		32,143		24,934		7,209			14,804		16,184		(1,380	)		62,904		56,938		5,966
Total revenue		706,916		621,392		85,524			174,285		208,288		(34,003	)		1,103,921		1,103,849		73

Cost of natural gas sold:
Natural gas - regulated		454,107		383,712		70,395			43,329		77,590		(34,261	)		578,860		588,007		(9,147	)
Other - non-regulated		16,859		1,015		15,844			3,599		5,187		(1,588	)		23,989		11,242		12,747
Total cost of natural gas sold		470,966		384,727		86,239			46,928		82,778		(35,850	)		602,849		599,249		3,600

Gas Utility margin (non-GAAP)		235,950		236,665		(715	)		127,357		125,510		1,847			501,072		504,600		(3,528	)

Operations and maintenance		94,827		86,441		8,386			82,922		85,311		(2,389	)		268,972		255,441		13,531
Depreciation and amortization		26,498		26,684		(186	)		29,035		29,616		(581	)		84,350		86,841		(2,491	)
Total operating expenses		121,325		113,125		8,200
									111,957		114,927		(2,970	)		353,322		342,282		11,040

Operating income	$	114,625	$	123,540	$	(8,915	)	$	15,400	$	10,583	$	4,817			147,750	$	162,318	$	(14,568	)

Three Months Ended ~~March 31,~~September 30, 2023, Compared to the Three Months Ended ~~March 31,~~September 30, 2022:

Gas Utility margin ~~decreased~~increased as a result of the following:


	(in millions)			(in millions)
New rates and rider recovery	$	5.2		$	2.6
Non-residential retail growth and demand		3.4
Residential growth and usage		0.9
Retail customer growth and demand					2.4
Mark-to-market on non-utility natural gas commodity contracts		(7.0	)		(1.4	)
Weather		(2.3	)		(1.3	)
Other		(0.9	)		(0.5	)
	$	(0.7	)	$	1.8

Operations and maintenance expense ~~increased~~decreased primarily due to ~~$6.3~~$2.4 million of ~~higher employee-related expenses and $1.7 million of higher materials and~~lower outside services expenses.

Depreciation and amortization was comparable to the same period in the prior year.

Nine Months Ended September 30, 2023, Compared to the Nine Months Ended September 30, 2022:

Gas Utility margin decreased as a result of the following:


	(in millions)
Prior year true-up of Winter Storm Uri carrying costs (a)	$	(10.3	)
Mark-to-market on non-utility natural gas commodity contracts		(5.4	)
Weather		(4.3	)
New rates and rider recovery		10.3
Retail customer growth and demand		7.1
Other		(0.9	)
	$	(3.5	)

(a)

In certain jurisdictions, we have commission approval to recover carrying costs on Winter Storm Uri regulatory assets which offset increased interest expense. During the second quarter of 2022, we accrued a one-time, $10.3 million true-up of these carrying costs to reflect commission authorized rates.

Operations and maintenance expense increased primarily due to $12.3 million of higher employee-related expenses.

Depreciation and amortization was comparable to the same period in the prior year.

Table of Contents

Operating Statistics


	Revenue (in thousands)				Quantities Sold and Transported (Dth)				Revenue (in thousands)								Quantities Sold and Transported (Dth)
	Three Months Ended March 31,				Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022		2023		2022		2023		2022		2023		2022		2023		2022
Residential	$	428,576	$	376,044		29,935,584		31,814,250	$	75,153	$	85,398	$	620,306	$	604,568		3,546,242		3,572,971		41,078,623		43,910,976
Commercial		182,523		158,642		14,004,072		14,631,703		28,629		36,819		255,430		256,643		2,399,834		2,374,179		20,462,092		21,505,127
Industrial		9,199		9,238		1,038,433		1,164,583		9,848		26,155		26,156		52,268		2,129,492		3,153,641		4,576,537		6,468,756
Other		1,444		2,772		-		-		3,057		2,566		7,305		7,638		-		-		-		-
Total Distribution		621,742		546,696		44,978,089		47,610,536		116,687		150,937		909,197		921,117		8,075,568		9,100,791		66,117,252		71,884,859
Transportation and Transmission		53,031		49,762		47,179,540		45,045,203		42,794		41,166		131,820		125,794		36,773,895		35,302,591		118,180,078		117,971,404
Total Regulated		674,773		596,458		92,157,629		92,655,739		159,481		192,104		1,041,017		1,046,910		44,849,463		44,403,382		184,297,330		189,856,263
Non-regulated Services (a)		32,143		24,934		-		-		14,804		16,184		62,904		56,938		-		-		-		-
Total Revenue and Quantities Sold	$	706,916	$	621,392		92,157,629		92,655,739	$	174,285	$	208,288	$	1,103,921	$	1,103,849		44,849,463		44,403,382		184,297,330		189,856,263

(a)

Includes Black Hills Energy Services and non-regulated services under the Service Guard Comfort Plan, Tech Services and HomeServe.


	Revenue (in thousands)				Quantities Sold and Transported (Dth)				Revenue (in thousands)								Quantities Sold and Transported (Dth)
	Three Months Ended March 31,				Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022		2023		2022		2023		2022		2023		2022		2023		2022
Arkansas Gas	$	126,637	$	127,809		11,475,750		12,927,736	$	27,166	$	30,663	$	189,034	$	210,287		4,372,453		4,396,388		21,098,256		22,769,574
Colorado Gas		144,886		120,053		14,055,294		13,418,684		31,503		32,239		227,852		202,620		3,588,228		3,408,420		23,283,092		23,192,881
Iowa Gas		125,457		120,579		14,291,408		15,376,182		18,784		24,580		168,137		187,209		5,790,254		5,103,212		27,193,172		28,658,007
Kansas Gas		72,221		58,851		11,173,502		10,989,067		22,724		38,029		118,478		132,362		9,084,974		9,202,701		27,382,033		28,954,575
Nebraska Gas		164,950		134,234		27,080,790		27,335,774		55,297		61,588		277,861		258,159		16,968,376		17,237,325		59,774,008		61,287,579
Wyoming Gas		72,765		59,866		14,080,885		12,608,296		18,811		21,189		122,559		113,212		5,045,178		5,055,336		25,566,769		24,993,647
Total Revenue and Quantities Sold	$	706,916	$	621,392		92,157,629		92,655,739	$	174,285	$	208,288	$	1,103,921	$	1,103,849		44,849,463		44,403,382		184,297,330		189,856,263


	Three Months Ended March 31,				Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022		2023		2022
Heating Degree Days	Actual	Variance from Normal	Actual	Variance from Normal	Actual	Variance from Normal	Actual	Variance from Normal	Actual	Variance from Normal	Actual	Variance from Normal
Arkansas Gas (a)	1,666	(18)%	2,099	---%	--	(100)%	16	(63)%	1,944	(18)%	2,386	(4)%
Colorado Gas	3,087	10%	2,946	1%	91	(22)%	84	(61)%	4,078	7%	3,847	(6)%
Iowa Gas	3,247	(6)%	3,579	6%	37	(59)%	92	(34)%	3,867	(10)%	4,474	7%
Kansas Gas (a)	2,373	(4)%	2,584	5%	6	(78)%	23	(58)%	2,749	6%	3,043	3%
Nebraska Gas	3,054	---%	3,041	---%	21	(67)%	48	(56)%	3,591	(5)%	3,768	---%
Wyoming Gas	3,624	21%	3,272	3%	180	5%	140	(55)%	4,953	14%	4,738	1%
Combined (b)	3,196	4%	3,165	2%	56	(35)%	70	(53)%	3,926	1%	4,003	---%

(a)

Arkansas Gas and Kansas Gas have weather normalization mechanisms that mitigate the weather impact on gross margins.

(b)

The combined heating degree days are calculated based on a weighted average of total customers by state excluding Kansas Gas due to its weather normalization mechanism. Arkansas Gas is partially excluded based on the weather normalization mechanism in effect from November through April.

Corporate and Other

Corporate and Other operating results were as follows (in thousands):

Three Months Ended March 31,

2023

2022

Variance

Operating (loss)
$
(802
)
$
(933
)
$
131


	Three Months Ended September 30,									Nine Months Ended September 30,
	2023			2022			Variance			2023			2022			Variance
Operating (loss)	$	(645	)	$	(587	)	$	(58	)	$	(2,275	)	$	(2,552	)	$	277

Three Months Ended ~~March 31,~~September 30, 2023, Compared to the Three Months Ended ~~March 31,~~September 30, 2022:

Operating loss was comparable to the same period in the prior year.

31Nine Months Ended September 30, 2023, Compared to the Nine Months Ended September 30, 2022:

Operating loss was comparable to the same period in the prior year.

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Consolidated Interest Expense, Other Income and Income Tax Expense


	Three Months Ended March 31,									Three Months Ended September 30,									Nine Months Ended September 30,
	2023			2022			Variance			2023			2022			Variance			2023			2022			Variance
	(in thousands)									(in thousands)
Interest expense, net	$	(43,504	)	$	(38,545	)	$	(4,959	)	$	(40,998	)	$	(40,019	)	$	(979	)	$	(126,023	)	$	(117,328	)	$	(8,695	)
Other income (expense), net		674			704			(30	)		(647	)		464			(1,111	)		(1,513	)		2,731			(4,244	)
Income tax (expense)		(14,673	)		(14,488	)		(185	)		(7,366	)		(2,090	)		(5,276	)		(15,950	)		(15,920	)		(30	)

Three Months Ended ~~March 31,~~September 30, 2023, Compared to the Three Months Ended ~~March 31,~~September 30, 2022:

Interest ~~Expense,~~expense, net

~~The increase in~~ Interest expense, net was ~~due~~comparable to ~~higher interest rates.~~the same period in the prior year.

Other ~~Income,~~income (expense), net

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

Income ~~Tax Expense~~tax (expense)

Income tax expense increased primarily due to higher pre-tax income and a higher effective tax rate. For the three months ended September 30, 2023, the effective tax rate was 13.1% compared to 5.2% for the same period in 2022. See Note 11 of the Condensed Notes to Consolidated Financial Statements for discussion of effective tax rate variances.

Nine Months Ended September 30, 2023, Compared to the Nine Months Ended September 30, 2022:

Interest expense, net

Interest expense, net increased due to higher interest rates partially offset by increased interest income on higher cash and cash equivalents balances.

Other income (expense), net

Other expense, net increased primarily due to higher non-service benefit plan costs driven by higher discount rates and higher costs for our non-qualified benefit plans which were driven by market performance.

Income tax (expense)

Income tax expense and the effective tax rate were comparable to the same period in the prior year. See Note 11 of the Condensed Notes to Consolidated Financial Statements for further information on the effective tax rate.

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Liquidity and Capital Resources

There have been no material changes in Liquidity and Capital Resources from those reported in Item 7 of our 2022 Annual Report on Form 10-K except as described below.

CASH FLOW ACTIVITIES

The following tables summarize our cash flows for the ~~three~~nine months ended ~~March 31,~~September 30, 2023, (in thousands):

Operating Activities:


	Three Months Ended March 31,									Nine Months Ended September 30,
	2023			2022			Variance			2023			2022			Variance
Cash earnings (net income plus non-cash adjustments)	$	198,280		$	208,572		$	(10,292	)	$	413,354		$	406,019		$	7,335
Changes in certain operating assets and liabilities:
Accounts receivable and other current assets		104,851			(36,246	)		141,097			346,310			(24,125	)		370,435
Accounts payable and accrued liabilities		(127,233	)		(8,422	)		(118,811	)		(186,500	)		5,963			(192,463	)
Regulatory assets and liabilities		154,666			98,528			56,138			199,093			118,330			80,763
		132,284			53,860			78,424			358,903			100,168			258,735
Other operating activities		(1,819	)		1,689			(3,508	)		(16,205	)		(11,900	)		(4,305	)
Net cash provided by (used in) operating activities	$	328,745		$	264,121		$	64,624
Net cash provided by operating activities										$	756,052		$	494,287		$	261,765

~~Three~~Nine Months Ended ~~March 31,~~September 30, 2023, Compared to the ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2022

Net cash provided by ~~(used in)~~ operating activities was ~~$65~~$261.8 million higher than the same period in 2022. The variance to the prior year was primarily attributable to:

•

Cash earnings (net income plus non-cash adjustments) were ~~$10~~$7.3 million ~~lower~~higher for the ~~three~~nine months ended ~~March 31,~~September 30, 2023 compared to the same period in the prior year primarily due to increased Electric and Gas Utility margins driven by new rates and increased rider revenues partially offset by higher operating expenses and higher interest expense.

•

Net inflows from changes in certain operating assets and liabilities were ~~$78~~$258.7 million higher, primarily attributable to:

Cash inflows increased by ~~$141~~$370.4 million as a result of changes in accounts receivable and other current assets primarily driven by higher collections on pass-through revenues and lower natural gas in storage inventories driven by fluctuations in commodity prices and timing of injections and withdrawals;

Cash outflows increased by ~~$119~~$192.5 million as a result of decreases in accounts payable and accrued liabilities primarily driven by fluctuations in commodity prices, payment timing of natural gas and power purchases and changes in other working capital requirements; and

Cash inflows increased by ~~$56~~$80.8 million as a result of changes in our regulatory assets and liabilities primarily due to higher recoveries of deferred gas and fuel cost adjustments driven by fluctuations in commodity prices and higher recoveries of Winter Storm Uri ~~incremental and carrying~~ costs from customers.

•

Cash outflows increased by ~~$3.5~~$4.3 million for other operating ~~activities.~~activities primarily due higher cloud computing licensing costs.

Investing Activities:


	Three Months Ended March 31,								Nine Months Ended September 30,
	2023			2022			Variance		2023			2022			Variance
Capital expenditures	$	(119,105	)	$	(136,779	)	$	17,674	$	(421,770	)	$	(466,302	)	$	44,532
Other investing activities		17,600			(1,065	)		18,665		17,985			(19	)		18,004
Net cash provided by (used in) investing activities	$	(101,505	)	$	(137,844	)	$	36,339
Net cash (used in) investing activities									$	(403,785	)	$	(466,321	)	$	62,536

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~~Three~~Nine Months Ended ~~March 31,~~September 30, 2023, Compared to the ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2022

Net cash used in investing activities was ~~$36~~$62.5 million lower than the same period in 2022. The variance to the prior year was primarily attributable to:

•

Cash outflows decreased by ~~$18~~$44.5 million as a result of lower capital expenditures which were driven by lower programmatic safety, reliability and integrity spending at our Gas and Electric Utilities; and

•

Cash inflows increased by ~~$19~~$18.0 million for other investing activities primarily due to proceeds from the sale of Northern Iowa Windpower assets.

Financing Activities:


	Three Months Ended March 31,									Nine Months Ended September 30,
	2023			2022			Variance			2023			2022			Variance
Dividends paid on common stock	$	(41,362	)	$	(38,533	)	$	(2,829	)	$	(125,446	)	$	(115,850	)	$	(9,596	)
Common stock issued		27,383			3,791			23,592			107,380			20,027			87,353
Short-term and long-term debt (repayments), net		(185,600	)		(78,700	)		(106,900	)
Short-term and long-term debt borrowings, net											264,400			81,170			183,230
Distributions to non-controlling interests		(4,494	)		(4,420	)		(74	)		(12,891	)		(11,678	)		(1,213	)
Other financing activities		(5,022	)		(878	)		(4,144	)		(12,193	)		1,647			(13,840	)
Net cash provided by (used in) financing activities	$	(209,095	)	$	(118,740	)	$	(90,355	)	$	221,250		$	(24,684	)	$	245,934

~~Three~~Nine Months Ended ~~March 31,~~September 30, 2023, Compared to the ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2022

Net cash ~~used in~~provided by financing activities was ~~$90~~$245.9 million higher than the same period in 2022. The variance to the prior year was primarily attributable to:

•

Cash ~~outflows~~inflows increased ~~$107~~$183.2 million due to ~~short-term~~current year long-term borrowings from the March 7, 2023 and September 15, 2023 debt ~~repayments~~offerings in excess of current and prior year short-term ~~and long-term borrowings.~~debt borrowings (repayments), net;

•

Cash inflows increased ~~$24~~$87.4 million due to higher issuances of common stock;

•

Cash outflows increased $9.6 million due to increased dividends paid on common stock; and

•

Cash outflows increased ~~$2.8 million due to increased dividends paid on common stock.~~

•

~~Cash outflows increased~~ by ~~$4.1~~$13.8 million for other financing ~~activities.~~activities primarily due to financing costs from the March 7, 2023 and September 15, 2023 debt offerings.

CAPITAL RESOURCES

~~Short-term Debt~~

See Note 5 of the Condensed Notes to Consolidated Financial Statements for ~~information on~~recent financing updates regarding our shelf registration, Revolving Credit Facility and CP ~~Program.~~Program, long-term debt and equity.

Covenant Requirements

The Revolving Credit Facility and Wyoming Electric’s financing agreements contain covenant requirements. We were in compliance with these covenants as of ~~March 31,~~September 30, 2023. See Note 5 of the Condensed Notes to Consolidated Financial Statements for more information.

~~Equity~~

~~See~~ ~~Note 5~~ ~~for information on our Equity issuances.~~

Future Financing Plans

We will continue to assess debt and equity needs to support our capital investment plans and other strategic objectives. We plan to fund our capital plan and strategic objectives by using cash generated from operating activities and various financing alternatives, which could include our Revolving Credit Facility, our CP Program, the issuance of common stock under our ATM program or in an opportunistic block trade. ~~We plan~~Proceeds from the September 15, 2023 debt offering, along with cash on hand, will be used to ~~re-finance a portion of~~repay our $525 million, 4.25%, senior unsecured notes due November 30, 2023 ~~at or before~~on their maturity date. We also plan to ~~renew~~re-finance our ~~ATM and shelf registration~~$600 million, 1.04%, senior unsecured notes due August 23, 2024, at or before ~~shelf expiration in August 2023.~~maturity date.

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CREDIT RATINGS

After assessing the current operating performance, liquidity and credit ratings of the Company, management believes that the Company will have access to the capital markets at prevailing market rates for companies with comparable credit ratings.

The following table represents the credit ratings and outlook and risk profile of BHC at ~~March 31,~~September 30, 2023:


Rating Agency	Senior Unsecured Rating	Outlook
S&P (a)	BBB+	Stable
Moody's (b)	Baa2	Stable
Fitch (c)	BBB+	Stable

(a)

On February 17, 2023, S&P reported BBB+ rating and maintained a Stable outlook.

(b)

On December 20, 2022, Moody’s reported Baa2 rating and maintained a Stable outlook.

(c)

On October 6, 2022, Fitch reported BBB+ rating and maintained a Stable outlook.

The following table represents the credit ratings of South Dakota Electric at ~~March 31,~~September 30, 2023:


Rating Agency	Senior Secured Rating
S&P (a)	A
Fitch (b)	A

(a)

On February 17, 2023, S&P reported A rating.

(b)

On October 6, 2022, Fitch reported A rating.

CAPITAL REQUIREMENTS

Capital Expenditures


	Actual		Forecasted										Actual		Forecasted
Capital Expenditures by Segment	Three Months Ended March 31, 2023 (a)		2023 (b)		2024		2025		2026		2027		Nine Months Ended September 30, 2023 (a)		2023 (b)		2024		2025		2026		2027
(in millions)
Electric Utilities	$	48	$	212	$	348	$	268	$	184	$	163	$	156	$	212	$	348	$	268	$	184	$	163
Gas Utilities		55		386		452		412		393		444		261		386		452		412		393		444
Corporate and Other		1		17		19		20		19		18		4		17		19		20		19		18
Incremental Projects (c)		-		-		-		-		104		75		-		-		-		-		104		75
	$	104	$	615	$	819	$	700	$	700	$	700	$	421	$	615	$	819	$	700	$	700	$	700

(a)

Includes accruals for property, plant and equipment as disclosed in supplemental cash flow information in the Consolidated Statements of Cash Flows in the Consolidated Financial Statements.

(b)

Includes actual capital expenditures for the ~~three~~nine months ended ~~March 31,~~September 30, 2023.

(c)

These represent projects that are being evaluated by our segments for timing, cost and other factors.

Dividends

Dividends paid on our common stock totaled ~~$41~~$125.4 million for the ~~three~~nine months ended ~~March 31,~~September 30, 2023, or $0.625 per share per quarter. On ~~April 24,~~October 23, 2023, our board of directors declared a quarterly dividend of $0.625 per share payable ~~June~~December 1, 2023, equivalent to an annual dividend of $2.50 per share. The amount of any future cash dividends to be declared and paid, if any, will depend upon, among other things, our financial condition, funds from operations, the level of our capital expenditures, restrictions under our Revolving Credit Facility and our future business prospects.

Funding Status of Employee Benefit Plans

Based on the fair value of assets and estimated discount rate used to value benefit obligations as of ~~March 31,~~September 30, 2023, we estimate the unfunded status of our employee benefit plans to be approximately ~~$32~~$38 million compared to $35 million at December 31, 2022. We have implemented various de-risking strategies including lump sum buyouts, the purchase of annuities and the reduction of return-seeking assets over time to a more liability-hedged portfolio. As a result, recent capital markets volatility had a limited impact to our funded status and does not require interim re-measurement of our pension plan assets or defined benefit obligations.

Table of Contents

Critical Accounting Estimates

A summary of our critical accounting estimates is included in our 2022 Annual Report on Form 10-K. There were no material changes made as of ~~March 31,~~September 30, 2023.

~~Table of Contents~~

New Accounting Pronouncements

Other than the pronouncements reported in our 2022 Annual Report on Form 10-K and those discussed in Note 1 of the Condensed Notes to Consolidated Financial Statements, there have been no new accounting pronouncements that are expected to have a material effect on our financial position, results of operations or cash flows.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

There have been no material changes to our quantitative and qualitative disclosures about market risk previously disclosed in Item 7A of our 2022 Annual Report on Form 10-K.

ITEM 4. CONTROLS AND PROCEDURES

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 amended (the “Exchange Act”)) as of ~~March 31,~~September 30, 2023. Based on their evaluation, they have concluded that our disclosure controls and procedures were effective at ~~March 31,~~September 30, 2023.

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 Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC’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,~~September 30, 2023, there have been no changes in our internal controls over financial reporting that have materially affected or are reasonably likely to materially affect our internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

For information regarding legal proceedings, seeNote 3 of the Condensed Notes to Consolidated Financial Statements and Note 3 in Item 8 of our 2022 Annual Report on Form 10-K.

ITEM 1A. RISK FACTORS

There are no material changes to the risk factors previously disclosed in Item 1A of Part I in our 2022 Annual Report on Form 10-K.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

The following table contains monthly information about our acquisitions of equity securities for the three months ended ~~March 31,~~September 30, 2023:

Period
Total Number of Shares Purchased (a)

Average Price Paid per Share

Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs

Maximum Number (or Approximate Dollar Value) of Shares That May Yet Be Purchased Under the Plans or Programs

January 1, 2023 - January 31, 2023

1

$
70.33

-

-

February 1, 2023 - February 28, 2023

12,235

64.14

-

-

March 1, 2023 - March 31, 2023

2

61.15

-

-

Total

12,238

$
64.14

-

-


Period	Total Number of Shares Purchased (a)		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs		Maximum Number (or Approximate Dollar Value) of Shares That May Yet Be Purchased Under the Plans or Programs
July 1, 2023 - July 31, 2023		1	$	60.27		-		-
August 1, 2023 - August 31, 2023		1,171		56.89		-		-
September 1, 2023 - September 30, 2023		2		54.74		-		-
Total		1,174	$	56.89		-		-

(a)

Shares were acquired under the share withholding provisions of the Amended and Restated 2015 Omnibus Incentive Plan for payment of taxes associated with the vesting of various equity compensation plans.

Table of Contents

ITEM 4. MINE SAFETY DISCLOSURES

Information concerning mine safety violations or other regulatory matters required by Sections 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act is included in Exhibit 95.

36ITEM 5. OTHER INFORMATION

~~Table of Contents~~

None of our directors or officers adopted, modified, or terminated a Rule 10b5-1 trading arrangement or a non-Rule 10b5-1 trading arrangement during the three months ended September 30, 2023.

ITEM 6. EXHIBITS

Exhibits filed herewithin are designated by an asterisk (*). All exhibits not so designated are incorporated by reference to a prior filing, as indicated. ~~Items constituting a board of director or management compensatory plan are designated by a cross (†).~~


Exhibit Number	Description

4.1	~~Eleventh~~Twelfth Supplemental Indenture dated as of ~~March 7,~~September 15, 2023 (filed as Exhibit 4.1 to the ~~Registrant's~~Registrant’s Form 8-K filed on ~~March 7,~~September 15, 2023).
~~10.1*†~~	~~Letter Agreement between Black Hills Corporation and Jennifer C. Landis~~
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.
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.
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.
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.
95*	Mine Safety and Health Administration Safety Data.
101.INS*	XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH*	XBRL Taxonomy Extension Schema Document
101.CAL*	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB*	XBRL Taxonomy Extension Label Linkbase Document
101.PRE*	XBRL Taxonomy Extension Presentation Linkbase Document
104*	Cover Page Interactive Data File (formatted as inline XBRL and contained in Exhibit 101)

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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 CORPORATION


		/s/ Linden R. Evans
		Linden R. Evans, President and
		Chief Executive Officer

		/s/ Kimberly F. Nooney
		Kimberly F. Nooney, Senior Vice President and
		Chief Financial Officer

Dated:	~~May 4,~~November 2, 2023

3842


Three Months Ended March 31, 2022	Electric Utilities		Gas Utilities		Inter-company Revenues			Total
Customer types:	(in thousands)
Retail	$	172,806	$	561,013	$	-		$	733,819
Transportation		-		49,523		(99	)		49,424
Wholesale		10,275		-		-			10,275
Market - off-system sales		7,154		238		-			7,392
Transmission/Other		15,433		9,575		(4,149	)		20,859
Revenue from contracts with customers	$	205,668	$	620,349	$	(4,248	)	$	821,769
Other revenues		870		1,043		(112	)		1,801
Total revenues	$	206,538	$	621,392	$	(4,360	)	$	823,570

Timing of revenue recognition:
Services transferred at a point in time	$	7,113	$	-	$	-		$	7,113
Services transferred over time		198,555		620,349		(4,248	)		814,656
Revenue from contracts with customers	$	205,668	$	620,349	$	(4,248	)	$	821,769


	External Operating Revenue				Inter-company Operating Revenue
Three Months Ended March 31, 2023	Contract Customers		Other Revenues		Contract Customers			Other Revenues		Total Revenues
Segment:
Electric Utilities	$	215,012	$	881	$	2,816		$	-	$	218,709
Gas Utilities		697,043		8,223		1,650			-		706,916
Inter-company eliminations		-		-		(4,466	)		-		(4,466	)
Total	$	912,055	$	9,104	$	-		$	-	$	921,159

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