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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
☒    Quarterly Report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
For the quarterly period ended March 31, 2023 or
☐    Transition Report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
Commission File Number 0-53713 
OTTER TAIL CORPORATION
(Exact name of registrant as specified in its charter) 
Minnesota
(State or other jurisdiction of incorporation or organization)
27-0383995
(I.R.S. Employer Identification No.)
215 South Cascade Street, Box 496, Fergus Falls, Minnesota
(Address of principal executive offices)
56538-0496
(Zip Code)
Registrant's telephone number, including area code: 866-410-8780
Securities registered pursuant to Section 12(b) of the Act: 
Title of each classTrading Symbol(s)Name of each exchange on which registered
Common Shares, par value $5.00 per shareOTTRThe Nasdaq Stock Market LLC
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 or a smaller reporting 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. (Check one): 
 
Large Accelerated Filer ☑
Accelerated Filer ☐
 
Non-Accelerated Filer ☐
Smaller Reporting Company ☐
Emerging Growth Company ☐
 
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  ☐ 
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 registrant's classes of common stock, as of the latest practicable date:
41,710,621 Common Shares ($5 par value) as of April 28, 2023. 


TABLE OF CONTENTS

1
DEFINITIONS
The following abbreviations or acronyms are used in the text.
AMDTAdvanced Meter and Distribution TechnologyMPUCMinnesota Public Utilities Commission
ARPAlternative Revenue ProgramNDDEQNorth Dakota Department of Environmental Quality
BTDBTD Manufacturing, Inc.NDPSCNorth Dakota Public Service Commission
CIPConservation Improvement ProgramOTCOtter Tail Corporation
EAREnergy Adjustment RiderOTPOtter Tail Power Company
EITEEnergy Intensive, Trade Exposed RiderPIRPhase-In Rider
EPAEnvironmental Protection AgencyPSLRAPrivate Securities Litigation Reform Act of 1995
ESSRPExecutive Survivor and Supplemental Retirement PlanPTCProduction Tax Credits
FERCFederal Energy Regulatory CommissionPVCPolyvinyl chloride
GCRGeneration Cost Recovery RiderRHRRegional Haze Rule
ISOIndependent System OperatorROEReturn on equity
IRPIntegrated Resource PlanRRRRenewable Resource Rider
kwhkilowatt-hourSECSecurities and Exchange Commission
MerricourtMerricourt Wind Energy CenterT.O. PlasticsT.O. Plastics, Inc.
MISOMidcontinent Independent System Operator, Inc.TCRTransmission Cost Recovery Rider
FORWARD-LOOKING INFORMATION
This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 (the "PSLRA"). When used in this Form 10-Q and in future filings by Otter Tail Corporation (the "Company") with the Securities and Exchange Commission (SEC), in the Company’s press releases and in oral statements, words such as “anticipate,” “believe,” “could,” “estimate,” “expect,” "future," "goal," “intend,” "likely," “may,” “outlook,” “plan,” “possible,” “potential,” "probable," "projected," “should,” "target," “will,” “would” or similar expressions are intended to identify forward-looking statements within the meaning of the PSLRA. Such statements are based on current expectations and assumptions and entail various risks and uncertainties that could cause actual results to differ materially from those expressed in such forward-looking statements. The Company’s risks and uncertainties include, among other things, uncertainty of future investments and capital expenditures, rate base levels and rate base growth, long-term investment risk, seasonal weather patterns and extreme weather events, counterparty credit risk, future business volumes with key customers, reductions in our credit ratings, our ability to access capital markets on favorable terms, assumptions and costs relating to funding our employee benefit plans, our subsidiaries’ ability to make dividend payments, cyber security threats or data breaches, the impact of government legislation and regulation including foreign trade policy and environmental, health and safety laws and regulations, the impact of climate change including compliance with legislative and regulatory changes to address climate change, operational and economic risks associated with our electric generating and manufacturing facilities, risks associated with energy markets, the availability and pricing of resource materials, inflation cost pressures, attracting and maintaining a qualified and stable workforce, expectations regarding regulatory proceedings, and changing macroeconomic and industry conditions. These and other risks and uncertainties are more fully described in our filings with the SEC, including our most recently filed Annual Report on Form 10-K. Forward-looking statements speak only as of the date they are made, and we expressly disclaim any obligation to update any forward-looking information.
PART I. FINANCIAL INFORMATION
ITEM 1.FINANCIAL STATEMENTS

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OTTER TAIL CORPORATION
CONSOLIDATED BALANCE SHEETS (unaudited)
(in thousands, except share data)March 31,
2023		December 31,
2022
Assets  
Current Assets  
Cash and Cash Equivalents$104,080 $118,996 
Receivables, net of allowance for credit losses175,442 144,393 
Inventories144,767 145,952 
Regulatory Assets16,566 24,999 
Other Current Assets13,510 18,412 
Total Current Assets454,365 452,752 
Noncurrent Assets
Investments58,058 54,845 
Property, Plant and Equipment, net of accumulated depreciation2,289,491 2,212,717 
Regulatory Assets97,179 94,655 
Intangible Assets, net of accumulated amortization7,668 7,943 
Goodwill37,572 37,572 
Other Noncurrent Assets43,077 41,177 
Total Noncurrent Assets2,533,045 2,448,909 
Total Assets$2,987,410 $2,901,661 
Liabilities and Shareholders' Equity
Current Liabilities
Short-Term Debt$60,854 $8,204 
Accounts Payable93,543 104,400 
Accrued Salaries and Wages20,149 32,327 
Accrued Taxes23,415 19,340 
Regulatory Liabilities20,526 17,300 
Other Current Liabilities43,977 56,065 
Total Current Liabilities262,464 237,636 
Noncurrent Liabilities
Pension Benefit Liability33,185 33,210 
Other Postretirement Benefits Liability47,469 46,977 
Regulatory Liabilities245,071 244,497 
Deferred Income Taxes230,393 221,302 
Deferred Tax Credits15,730 15,916 
Other Noncurrent Liabilities65,439 60,985 
Total Noncurrent Liabilities637,287 622,887 
Commitments and Contingencies (Note 9)
Capitalization
Long-Term Debt823,882 823,821 
Shareholders' Equity
Common Shares: 50,000,000 shares authorized, $5 par value; 41,684,526 and 41,631,113 outstanding
at March 31, 2023 and December 31, 2022
208,423 208,156 
Additional Paid-In Capital424,948 423,034 
Retained Earnings629,437 585,212 
Accumulated Other Comprehensive Income969 915 
Total Shareholders' Equity1,263,777 1,217,317 
Total Capitalization2,087,659 2,041,138 
Total Liabilities and Shareholders' Equity$2,987,410 $2,901,661 
See accompanying notes to consolidated financial statements.
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OTTER TAIL CORPORATION
CONSOLIDATED STATEMENTS OF INCOME (unaudited)
Three Months Ended March 31,
(in thousands, except per-share amounts)20232022
Operating Revenues  
Electric$151,909 $130,416 
Product Sales187,172 244,488 
Total Operating Revenues339,081 374,904 
Operating Expenses
Electric Production Fuel11,492 14,853 
Electric Purchased Power41,825 20,529 
Electric Operating and Maintenance Expenses45,549 44,278 
Cost of Products Sold (excluding depreciation)112,369 151,759 
Other Nonelectric Expenses18,699 17,206 
Depreciation and Amortization23,856 23,548 
Electric Property Taxes4,621 4,432 
Total Operating Expenses258,411 276,605 
Operating Income80,670 98,299 
Other Income and (Expense)
Interest Expense(9,415)(8,948)
Nonservice Components of Postretirement Benefits2,412 22 
Other Income (Expense), net2,118 260 
Income Before Income Taxes75,785 89,633 
Income Tax Expense13,304 17,630 
Net Income$62,481 $72,003 
Weighted-Average Common Shares Outstanding:
Basic41,632 41,548 
Diluted41,977 41,871 
Earnings Per Share:
Basic$1.50 $1.73 
Diluted$1.49 $1.72 
See accompanying notes to consolidated financial statements.
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OTTER TAIL CORPORATION
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited)
Three Months Ended March 31,
(in thousands)20232022
Net Income$62,481 $72,003 
Other Comprehensive Income (Loss):
Unrealized Gain (Loss) on Available-for-Sale Securities, net of tax (expense) benefit of $(21) and $61
80 (231)
Pension and Other Postretirement Benefits, net of tax benefit of $9 and $67
(26)(190)
Total Other Comprehensive Income (Loss)54 (421)
Total Comprehensive Income$62,535 $71,582 
See accompanying notes to consolidated financial statements.
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OTTER TAIL CORPORATION
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY (unaudited)
(in thousands, except common shares outstanding)Common
Shares
Outstanding		Par Value,
Common
Shares		Additional Paid-In CapitalRetained
Earnings		Accumulated
Other
Comprehensive
Income (Loss)		Total Shareholders' Equity
Balance, December 31, 202241,631,113 $208,156 $423,034 $585,212 $915 $1,217,317 
Stock Issued Under Share-Based Compensation Plans, net of shares withheld for employee taxes53,413 267 (3,355)— — (3,088)
Net Income— — — 62,481 — 62,481 
Other Comprehensive Income— — — — 54 54 
Stock Compensation Expense— — 5,269 — — 5,269 
Common Dividends ($0.4375 per share)
— — — (18,256)— (18,256)
Balance, March 31, 202341,684,526 $208,423 $424,948 $629,437 $969 $1,263,777 
Balance, December 31, 202141,551,524 $207,758 $419,760 $369,783 $(6,524)$990,777 
Stock Issued Under Share-Based Compensation Plans, net of shares withheld for employee taxes54,360 271 (3,215)— — (2,944)
Net Income— — — 72,003 — 72,003 
Other Comprehensive Loss— — — — (421)(421)
Stock Compensation Expense— — 4,904 — — 4,904 
Common Dividends ($0.4125 per share)
— — — (17,181)— (17,181)
Balance, March 31, 202241,605,884 $208,029 $421,449 $424,605 $(6,945)$1,047,138 
See accompanying notes to consolidated financial statements.
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OTTER TAIL CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)
Three Months Ended March 31,
(in thousands)20232022
Operating Activities  
Net Income$62,481 $72,003 
Adjustments to Reconcile Net Income to Net Cash Provided by Operating Activities:
Depreciation and Amortization23,856 23,548 
Deferred Tax Credits(186)(186)
Deferred Income Taxes8,028 14,342 
Discretionary Contribution to Pension Plan— (20,000)
Allowance for Equity Funds Used During Construction(174)(260)
Stock Compensation Expense5,269 4,904 
Other, Net(1,562)866 
Changes in Operating Assets and Liabilities:
Receivables(31,049)(43,943)
Inventories1,460 3,403 
Regulatory Assets7,147 4,468 
Other Assets5,278 3,729 
Accounts Payable(7,387)(12,533)
Accrued and Other Liabilities(19,617)(7,859)
Regulatory Liabilities4,420 2,812 
Pension and Other Postretirement Benefits(2,411)122 
Net Cash Provided by Operating Activities55,553 45,416 
Investing Activities
Capital Expenditures(98,101)(28,710)
Proceeds from Disposal of Noncurrent Assets1,030 878 
Cash Used for Investments and Other Assets(3,308)(3,617)
Net Cash Used in Investing Activities(100,379)(31,449)
Financing Activities
Net Borrowings on Short-Term Debt52,650 6,608 
Dividends Paid(18,256)(17,181)
Payments for Shares Withheld for Employee Tax Obligations(3,088)(2,942)
Other, net(1,396)(618)
Net Cash Provided by (Used in) Financing Activities29,910 (14,133)
Net Change in Cash and Cash Equivalents(14,916)(166)
Cash and Cash Equivalents at Beginning of Period118,996 1,537 
Cash and Cash Equivalents at End of Period$104,080 $1,371 
Supplemental Disclosure of Noncash Investing Activities
Accrued Property, Plant and Equipment Additions$10,346 $9,165 
See accompanying notes to consolidated financial statements
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OTTER TAIL CORPORATION
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (unaudited)
1. Summary of Significant Accounting Policies
Overview
Otter Tail Corporation (OTC) and its subsidiaries (collectively, the "Company", "us", "our" or "we") form a diverse, multi-platform business consisting of a vertically integrated, regulated utility with generation, transmission and distribution facilities complemented by manufacturing businesses providing metal fabrication for custom machine parts and metal components, manufacturing of extruded and thermoformed plastic products, and manufacturing of polyvinyl chloride (PVC) pipe products. We classify our business into three segments: Electric, Manufacturing and Plastics.
Basis of Presentation
The unaudited consolidated financial statements included herein have been prepared pursuant to the rules and regulations of the SEC for interim reporting. Accordingly, they do not include all the information and footnotes required by generally accepted accounting principles. In the opinion of management, we have included all adjustments, including normal recurring accruals, necessary for a fair presentation of the consolidated financial statements for the periods presented. The consolidated financial statements and condensed notes thereto should be read in conjunction with the consolidated financial statements and notes included in our Annual Report on Form 10-K for the fiscal year ended December 31, 2022.
Because of the seasonality of our businesses and other factors, the earnings for the three months ended March 31, 2023 should not be taken as an indication of earnings for all or any part of the balance of the current year or as an indication of earnings for future years.
Use of Estimates
We use estimates based on the best information available in recording transactions and balances resulting from business operations. As better information becomes available or actual amounts are known, the recorded estimates are revised. Consequently, operating results can be affected by revisions to prior accounting estimates.
Concentration of Deposits and Investments
The Company has financial instruments that potentially subject us to a concentration risk, including cash and cash equivalents held in deposit and money market accounts with various financial institutions. These deposits are guaranteed by the Federal Deposit Insurance Corporation up to an insurance limit of $250,000. Currently, our cash and cash equivalents significantly exceed federally insured levels.
2. Segment Information
We classify our business into three segments, Electric, Manufacturing and Plastics, consistent with our business strategy, organizational structure and our internal reporting and review processes used by our chief operating decision maker to make decisions regarding allocation of resources, to assess operating performance and to make strategic decisions.
Certain assets and costs are not allocated to our operating segments. Corporate operating costs include items such as corporate staff and overhead costs, the results of our captive insurance company and other items excluded from the measurement of operating segment performance. Corporate assets consist primarily of cash and cash equivalents, prepaid expenses, investments and fixed assets. Corporate is not an operating segment, rather it is added to operating segment totals to reconcile to consolidated amounts.
Information for each segment and our unallocated corporate costs for the three months ended March 31, 2023 and 2022 are as follows:
Three Months Ended March 31,
(in thousands)20232022
Operating Revenue
Electric$151,909 $130,416 
Manufacturing106,782 104,957 
Plastics80,390 139,531 
Total$339,081 $374,904 
Net Income (Loss)
Electric$23,221 $19,233 
Manufacturing6,862 4,084 
Plastics33,686 50,846 
Corporate(1,288)(2,160)
Total$62,481 $72,003 
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The following provides the identifiable assets by segment and corporate assets as of March 31, 2023 and December 31, 2022:
(in thousands)March 31,
2023		December 31,
2022
Identifiable Assets
Electric$2,418,544 $2,351,961 
Manufacturing256,451 245,869 
Plastics149,256 126,318 
Corporate163,159 177,513 
Total$2,987,410 $2,901,661 
3. Revenue
Presented below are our operating revenues to external customers, in total and by amounts arising from contracts with customers and alternative revenue program (ARP) arrangements, disaggregated by revenue source and segment for the three months ended March 31, 2023 and 2022:
Three Months Ended March 31,
(in thousands)20232022
Operating Revenues
Electric Segment
Retail: Residential$43,972 $40,561 
Retail: Commercial and Industrial90,489 71,171 
Retail: Other1,992 1,907 
  Total Retail136,453 113,639 
Transmission12,107 12,556 
Wholesale1,838 2,463 
Other1,511 1,758 
Total Electric Segment151,909 130,416 
Manufacturing Segment
Metal Parts and Tooling90,068 89,573 
Plastic Products and Tooling14,142 12,445 
Scrap Metal Sales2,572 2,939 
Total Manufacturing Segment106,782 104,957 
Plastics Segment
PVC Pipe80,390 139,531 
Total Operating Revenue339,081 374,904 
Less: Non-contract Revenues Included Above
Electric Segment - ARP Revenues(1,210)(2,460)
Total Operating Revenues from Contracts with Customers$340,291 $377,364 
4. Select Balance Sheet Information
Receivables and Allowance for Credit Losses
Receivables as of March 31, 2023 and December 31, 2022 are as follows:
(in thousands)March 31,
2023		December 31,
2022
Receivables
Trade$145,337 $112,126 
Other8,918 9,983 
Unbilled Receivables23,378 23,932 
Total Receivables177,633 146,041 
Less: Allowance for Credit Losses2,191 1,648 
Receivables, net of allowance for credit losses$175,442 $144,393 
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The following is a summary of activity in the allowance for credit losses for the three months ended March 31, 2023 and 2022:
(in thousands)20232022
Beginning Balance, January 1$1,648 $1,836 
Additions Charged to Expense737 210 
Reductions for Amounts Written Off, Net of Recoveries(194)(259)
Ending Balance, March 31$2,191 $1,787 
Inventories
Inventories consist of the following as of March 31, 2023 and December 31, 2022:
(in thousands)March 31,
2023		December 31,
2022
Raw Material, Fuel and Supplies$73,860 $70,374 
Work in Process30,602 31,766 
Finished Goods40,305 43,812 
Total Inventories$144,767 $145,952 
Investments
The following is a summary of our investments as of March 31, 2023 and December 31, 2022:
(in thousands)March 31,
2023		December 31,
2022
Corporate-Owned Life Insurance Policies$39,781 $38,991 
Corporate and Government Debt Securities8,971 8,761 
Money Market Funds2,148 1,560 
Mutual Funds7,128 5,503 
Other Investments30 30 
Total Investments$58,058 $54,845 
The amount of unrealized gains and losses on debt securities as of March 31, 2023 and December 31, 2022 was not material and no unrealized losses were deemed to be other-than-temporary. In addition, the amount of unrealized gains and losses on marketable equity securities still held as of March 31, 2023 and December 31, 2022 was not material.
Property, Plant and Equipment
Major classes of property, plant and equipment as of March 31, 2023 and December 31, 2022 include:
(in thousands)March 31,
2023		December 31,
2022
Electric Plant  
Electric Plant in Service$2,917,699 $2,844,379 
Construction Work in Progress128,328 113,932 
Total Gross Electric Plant3,046,027 2,958,311 
Less Accumulated Depreciation and Amortization876,330 859,988 
Net Electric Plant2,169,697 2,098,323 
Nonelectric Property, Plant and Equipment
Nonelectric Property, Plant and Equipment in Service295,548 293,928 
Construction Work in Progress22,840 15,170 
Total Gross Nonelectric Property, Plant and Equipment318,388 309,098 
Less Accumulated Depreciation and Amortization198,594 194,704 
Net Nonelectric Property, Plant and Equipment119,794 114,394 
Net Property, Plant and Equipment$2,289,491 $2,212,717 
On January 3, 2023, we purchased the Ashtabula III wind farm, located in eastern North Dakota, which consists of 39 wind turbines and the related infrastructure, adding 62.4 megawatts of nameplate capacity to our owned generation assets. The total purchase price of the acquisition was $50.6 million. In addition to the acquired assets, we also recognized a $3.3 million asset retirement obligation liability associated with the wind farm and became party to the land easement agreements with the landowners of the wind farm.
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5. Regulatory Matters
Regulatory Assets and Liabilities
The following presents our current and long-term regulatory assets and liabilities as of March 31, 2023 and December 31, 2022 and the period we expect to recover or refund such amounts:
Period ofMarch 31, 2023December 31, 2022
(in thousands)Recovery/RefundCurrentLong-TermCurrentLong Term
Regulatory Assets
Pension and Other Postretirement Benefit Plans1
See Below$— $89,474 $— $88,354 
Alternative Revenue Program Riders2
Up to 2 years
3,705 3,272 5,679 2,508 
Asset Retirement Obligations1
Asset lives— 1,670 — 1,467 
Deferred Income TaxesAsset lives— 729 — — 
ISO Cost Recovery Trackers1
Up to 2 years
432 201 575 314 
Unrecovered Project Costs1
Up to 5 years
319 916 320 990 
Deferred Rate Case Expenses1
Up to 3 years
377 660 377 754 
Fuel Clause Adjustments1
Up to 1 year
11,361 — 10,893 — 
Derivative Instruments1
Up to 1 year
347 — 7,130 — 
Other1
Various25 257 25 268 
Total Regulatory Assets$16,566 $97,179 $24,999 $94,655 
Regulatory Liabilities
Deferred Income TaxesAsset lives$— $130,429 $— $131,480 
Plant Removal ObligationsAsset lives8,492 106,181 8,509 105,733 
Fuel Clause Adjustments
Up to 1 year
3,654 — 365 — 
Alternative Revenue Program Riders
Up to 1 year
2,326 — 2,504 — 
North Dakota PTC RefundsAsset lives— 8,254 — 7,136 
Pension and Other Postretirement Benefit Plans
Up to 1 year
5,589 — 5,589 — 
OtherVarious465 207 333 148 
Total Regulatory Liabilities$20,526 $245,071 $17,300 $244,497 
1Costs subject to recovery without a rate of return.
2Amount eligible for recovery includes an incentive or rate of return.
6. Short-Term and Long-Term Borrowings
The following is a summary of our outstanding short- and long-term borrowings by borrower, OTC or Otter Tail Power Company (OTP), as of March 31, 2023 and December 31, 2022:
Short-Term Debt
The following is a summary of our lines of credit as of March 31, 2023 and December 31, 2022:
March 31, 2023December 31,
2022
(in thousands)Borrowing LimitAmount OutstandingLetters
of Credit		Amount AvailableAmount Available
OTC Credit Agreement$170,000 $— $— $170,000 $170,000 
OTP Credit Agreement170,000 60,854 9,573 99,573 152,223 
Total$340,000 $60,854 $9,573 $269,573 $322,223 
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Long-Term Debt
The following is a summary of outstanding long-term debt by borrower as of March 31, 2023 and December 31, 2022: 
(in thousands)
BorrowerDebt InstrumentRateMaturityMarch 31,
2023		December 31,
2022
OTCGuaranteed Senior Notes3.55%12/15/26$80,000 $80,000 
OTPSeries 2007C Senior Unsecured Notes6.37%08/02/2742,000 42,000 
OTPSeries 2013A Senior Unsecured Notes4.68%02/27/2960,000 60,000 
OTPSeries 2019A Senior Unsecured Notes3.07%10/10/2910,000 10,000 
OTPSeries 2020A Senior Unsecured Notes3.22%02/25/3010,000 10,000 
OTPSeries 2020B Senior Unsecured Notes3.22%08/20/3040,000 40,000 
OTPSeries 2021A Senior Unsecured Notes2.74%11/29/3140,000 40,000 
OTPSeries 2007D Senior Unsecured Notes6.47%08/20/3750,000 50,000 
OTPSeries 2019B Senior Unsecured Notes3.52%10/10/3926,000 26,000 
OTPSeries 2020C Senior Unsecured Notes3.62%02/25/4010,000 10,000 
OTPSeries 2013B Senior Unsecured Notes5.47%02/27/4490,000 90,000 
OTPSeries 2018A Senior Unsecured Notes4.07%02/07/48100,000 100,000 
OTPSeries 2019C Senior Unsecured Notes3.82%10/10/4964,000 64,000 
OTPSeries 2020D Senior Unsecured Notes3.92%02/25/5015,000 15,000 
OTPSeries 2021B Senior Unsecured Notes3.69%11/29/51100,000 100,000 
OTPSeries 2022A Senior Unsecured Notes3.77%05/20/5290,000 90,000 
Total$827,000 $827,000 
Less:Unamortized Long-Term Debt Issuance Costs3,118 3,179 
Total Long-Term Debt, Net of Unamortized Debt Issuance Costs$823,882 $823,821 
Financial Covenants
Certain of OTC's and OTP's short- and long-term debt agreements require the borrower, whether OTC or OTP, to maintain certain financial covenants, including a maximum debt to total capitalization ratio of 0.60 to 1.00, a minimum interest and dividend coverage ratio of 1.50 to 1.00, and a maximum level of priority indebtedness. As of March 31, 2023, OTC and OTP were in compliance with these financial covenants.
7. Employee Postretirement Benefits
Pension Plan and Other Postretirement Benefits
The Company sponsors a noncontributory funded pension plan (the "Pension Plan"), an unfunded, nonqualified Executive Survivor and Supplemental Retirement Plan (the "ESSRP"), both accounted for as defined benefit pension plans, and a postretirement healthcare plan accounted for as an other postretirement benefit plan.
The following table includes the components of net periodic benefit cost (income) related to our defined benefit pension plans and other postretirement benefits for the three months ended March 31, 2023 and 2022:
Three Months Ended March 31,
Pension Benefits (Pension Plan)Pension Benefits (ESSRP)Postretirement Benefits
(in thousands)202320222023202220232022
Service Cost$925 $1,644 $18 $49 $153 $335 
Interest Cost4,109 3,086 314 335 669 510 
Expected Return on Assets(6,479)(5,921)— — — — 
Amortization of Prior Service Cost— — — — (1,433)(1,433)
Amortization of Net Actuarial Loss— 1,966 — 142 — 766 
Net Periodic Benefit Cost (Income)$(1,445)$775 $332 $526 $(611)$178 
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The following table includes the impact of regulation on the recognition of periodic benefit cost (income) arising from pension and other postretirement benefits for the three months ended March 31, 2023 and 2022:
Three Months Ended March 31,
(in thousands)20232022
Net Periodic Benefit Cost (Income)$(1,724)$1,479 
Net Amount Amortized (Deferred) Due to the Effect of Regulation408 527 
Net Periodic Benefit Cost (Income) Recognized$(1,316)$2,006 
We had no minimum funding requirements for our Pension Plan or any other postretirement benefit plans as of December 31, 2022. We did not make any contributions to our Pension Plan during the three months ended March 31, 2023. We made discretionary contributions to our Pension Plan of $20.0 million during the three months ended March 31, 2022.
8. Income Taxes
The reconciliation of the statutory federal income tax rate to our effective tax rate for each of the three months ended March 31, 2023 and 2022 is as follows:
Three Months Ended
20232022
Income Taxes at Federal Statutory Rate$15,915 21.0 %$18,823 21.0 %
Increases (Decreases) in Tax from:
State Taxes on Income, Net of Federal Tax3,789 5.0 4,482 5.0 
Production Tax Credits (PTCs)(4,655)(6.1)(3,967)(4.4)
Amortization of Excess Deferred Income Taxes(798)(1.1)(1,177)(1.3)
North Dakota Wind Tax Credit Amortization, Net of Federal Tax(164)(0.2)(200)(0.2)
Allowance for Equity Funds Used During Construction(51)(0.1)(93)(0.1)
Other, Net(732)(0.9)(238)(0.3)
Income Tax Expense / Effective Tax Rate$13,304 17.6 %$17,630 19.7 %
9. Commitments and Contingencies
Commitments
Land Easements. Since 2013, we had purchased the wind-generated electricity from the Ashtabula III wind farm pursuant to a power purchase agreement. That agreement granted us the option to purchase the wind farm and on January 3, 2023, we completed the purchase for $50.6 million. In connection with the purchase, we assumed 51 land easements, not classified as leases, which require annual payments. The remaining payments to be made under the easements total $4.2 million and the remaining terms of the agreements extend into 2034.
Contingencies
FERC Return on Equity (ROE). In November 2013 and February 2015, customers filed complaints with the Federal Energy Regulatory Commission (FERC) seeking to reduce the return on equity component of the transmission rates that Midcontinent Independent System Operator, Inc. (MISO) transmission owners, including OTP, may collect under the MISO tariff rate. FERC's most recent order, issued on November 19, 2020, adopted a revised ROE methodology and set the base ROE at 10.02% (10.52% with an adder) effective for the fifteen-month period from November 2013 to February 2015 and on a prospective basis beginning in September 2016. The order also dismissed any complaints covering the period from February 2015 to May 2016. On August 9, 2022, the U.S. Court of Appeals for the District of Columbia Circuit vacated the FERC order citing a lack of reasoned explanation by FERC in its adoption of its revised ROE methodology as outlined in its November 2020 order. The U.S. Court of Appeals remanded the matter to FERC to reopen the proceedings.
Significant uncertainty exists as to how FERC will proceed upon remand and there is no prescribed timeline under which FERC must act. We have deferred recognition and recorded a refund liability of $2.6 million as of March 31, 2023. This refund liability reflects our best estimate of amounts previously collected from customers under the MISO tariff rate that may be required to be refunded to customers once all regulatory and judicial proceedings are complete and a final ROE is established for the periods outlined above.
Regional Haze Rule (RHR). The RHR was adopted in an effort to improve visibility in national parks and wilderness areas. The RHR requires states, in coordination with the Environmental Protection Agency (EPA) and other governmental agencies, to develop and implement plans to achieve natural visibility conditions. The second RHR implementation period covers the years 2018-2028. States are required to submit a state implementation plan to assess reasonable progress with the RHR and determine what additional emission reductions are appropriate, if any.
Coyote Station, OTP's jointly owned coal-fired power plant in North Dakota, is subject to assessment in the second implementation period under the North Dakota state implementation plan. The North Dakota Department of Environmental Quality (NDDEQ) submitted its state implementation plan to the EPA for approval in August, 2022. In its plan, the NDDEQ concluded it is not reasonable to require additional emission controls during
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this planning period. The EPA has previously expressed disagreement with the NDDEQ's recommendation to forgo additional emission controls and has indicated that such a plan is not likely to be accepted.
We cannot predict with certainty the impact the state implementation plan may have on our business until the plan has been approved or otherwise acted on by the EPA. However, significant emission control investments could be required and the recovery of such costs from customers would require regulatory approval. Alternatively, investments in emission control equipment may prove to be uneconomic and result in the early retirement of or the sale of our interest in Coyote Station, subject to regulatory approval. We cannot estimate the ultimate financial effects such a retirement or sale may have on our consolidated operating results, financial position or cash flows, but such amounts could be material and the recovery of such costs in rates would be subject to regulatory approval.
Self-Funding of Transmission Upgrades. The FERC has granted transmission owners within MISO the unilateral authority to determine the funding mechanism for interconnection transmission upgrades that are necessary to accommodate new generation facilities connecting to the electrical grid. Under existing FERC orders, transmission owners can unilaterally determine whether the generator pays the transmission owner in advance for the transmission upgrade or, alternatively, the transmission owner can elect to fund the upgrade and recover over time from the generator the cost of and a return on the upgrade investment (a self-funding). FERC’s orders granting transmission owners this unilateral funding authority has been judicially contested on the basis that transmission owners may be motivated to discriminate among generators in making funding determinations. In the most recent judicial proceedings, the petitioners argued to the U.S. Court of Appeals for the District of Columbia that FERC did not comply with a previous judicial order to fully develop a record regarding the risk of discrimination and the financial risk absorbed by transmission owners for generator-funded upgrades. On December 2, 2022, the Court of Appeals ruled in favor of the petitioners remanding the matter to FERC, instructing the agency to adequately explain the basis of its orders. The Court of Appeals decision did not vacate transmission owners’ unilateral funding authority.
OTP, as a transmission owner in MISO, has exercised its authority and elected to self-fund previous transmission upgrades necessary to accommodate new system generation. Under such an election, OTP is recovering the cost of the transmission upgrade and a return on that investment from the generator over a contractual period of time. Should FERC, on remand from the Court of Appeals, eliminate transmission owners’ unilateral funding authority, on either a prospective or retrospective basis, our financial results would be impacted. We cannot at this time reasonably predict the outcome of this matter given the uncertainty as to how and when FERC may respond to the judicial remand.
Other Contingencies. We are party to litigation and regulatory matters arising in the normal course of business. We regularly analyze relevant information and, as necessary, estimate and record accrued liabilities for legal, regulatory enforcement and other matters in which a loss is probable of occurring and can be reasonably estimated. We believe the effect on our consolidated operating results, financial position and cash flows, if any, for the disposition of all matters pending as of March 31, 2023, other than those discussed above, will not be material.
10. Stockholders' Equity
Registration Statements
On May 3, 2021, we filed a shelf registration statement with the SEC under which we may offer for sale, from time to time, either separately or together in any combination, equity, debt or other securities described in the shelf registration statement. No new debt or equity has been issued pursuant to the registration statement. The registration statement expires in May 2024.
On May 3, 2021, we filed a second registration statement with the SEC for the issuance of up to 1,500,000 common shares under an Automatic Dividend Reinvestment and a Share Purchase Plan, which provides shareholders, retail customers of OTP and other interested investors methods of purchasing our common shares, by reinvesting their dividends or making optional cash investments. Shares purchased under the plan may be newly issued common shares or common shares purchased on the open market. During the three months ended March 31, 2023, we issued 30,893 shares under this plan. We repurchased a sufficient number of shares on the open market to satisfy issuance under the plan; accordingly, no proceeds from the issuance were received. As of March 31, 2023, there were 1,220,100 shares available for purchase or issuance under the plan. The registration statement expires in May 2024.
Dividend Restrictions
OTC is a holding company with no significant operations of its own. The primary source of funds for payments of dividends to OTC's shareholders is from dividends paid or distributions made by OTC's subsidiaries. As a result of certain statutory limitations or regulatory or financing agreements, the amount of distributions allowed to be made by OTC's subsidiaries or the amount of dividends paid by OTC could be restricted. Both the OTC Credit Agreement and OTP Credit Agreement contain restrictions on the payment of cash dividends upon a default or event of default, including failure to maintain certain financial covenants. As of March 31, 2023, we were in compliance with these financial covenants.
Under the Federal Power Act, a public utility may not pay dividends from any funds properly included in a capital account. What constitutes “funds properly included in a capital account” is undefined in the Federal Power Act or the related regulations; however, the FERC has consistently interpreted the provision to allow dividends to be paid as long as i) the source of the dividends is clearly disclosed, ii) the dividend is not excessive and iii) there is no self-dealing on the part of corporate officials.
The Minnesota Public Utilities Commission (MPUC) indirectly limits the amount of dividends OTP can pay to OTC by requiring an equity-to-total-capitalization ratio between 47.5% and 58.0% based on OTP’s capital structure petition effective by order of the MPUC on November 8, 2022. As of March 31, 2023, OTP’s equity-to-total-capitalization ratio, including short-term debt, was 53.3% and its net assets restricted from distribution totaled approximately $758.1 million. Under the MPUC order, total capitalization for OTP cannot exceed $1.8 billion.
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11. Accumulated Other Comprehensive Income (Loss)
The following presents the changes in accumulated other comprehensive loss for the three months ended March 31, 2023 and 2022:
Three Months Ended March 31,
20232022
(in thousands)Pension and Other Postretirement BenefitsNet Unrealized Gains (Losses) on Available-for-Sale SecuritiesTotalPension and Other Postretirement BenefitsNet Unrealized Gains (Losses) on Available-for-Sale SecuritiesTotal
Balance, Beginning of Period$1,334 $(419)$915 $(6,537)$13 $(6,524)
Other Comprehensive Income (Loss) Before Reclassifications, net of tax— 80 80 — (231)(231)
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)(26)
(1)
— (26)(190)
(1)
— (190)
Total Other Comprehensive Income (Loss)(26)80 54 (190)(231)(421)
Balance, End of Period$1,308 $(339)$969 $(6,727)$(218)$(6,945)
(1) Included in the computation of net periodic pension and other postretirement benefit costs. See Note 7.
12. Share-Based Payments
Stock Compensation Expense
Stock-based compensation expense arising from our employee stock purchase plan and share-based compensation plans recognized within operating expenses in the consolidated statements of income amounted to $5.3 million and $4.9 million for the three months ended March 31, 2023 and 2022, respectively.
Restricted Stock Awards. We grant restricted stock awards to members of our Board of Directors and restricted stock units to certain key employees. The awards vest, depending on award type and recipient, either ratably over periods of three or four years or cliff vest after four years. Vesting is accelerated in certain circumstances, including on retirement.
The following is a summary of stock award activity for the three months ended March 31, 2023:
SharesWeighted Average
Grant-Date
Fair Value
Nonvested, January 1, 2023
141,551 $49.83 
Granted17,900 64.65 
Vested(18,600)50.94 
Forfeited— — 
Nonvested, March 31, 2023
140,851 $51.57 
The fair value of vested awards was $1.2 million during the three months ended March 31, 2023 and 2022.
Stock Performance Awards. Stock performance awards are granted to executive officers and certain other key employees. The awards vest at the end of a three-year performance period. The number of common shares awarded, if any, at the end of the performance period ranges from zero to 150% of the target amount based on two performance measures: i) total shareholder return relative to a peer group and ii) return on equity. Vesting of the awards is accelerated in certain circumstances, including on retirement. The amount of common shares awarded on an accelerated vesting is based either on actual performance at the end of the performance period or the amount of common shares earned at target.
The grant date fair value of stock performance awards granted during the three months ended March 31, 2023 and 2022 was determined using a Monte Carlo fair value simulation model incorporating the following assumptions:
20232022
Risk-free interest rate4.15 %1.52 %
Expected term (in years)3.003.00
Expected volatility34.00 %32.00 %
Dividend yield2.50 %2.90 %
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The risk-free interest rate was derived from yields on U.S. government bonds of a similar term. The expected term of the award is equal to the three-year performance period. Expected volatility was estimated based on actual historical volatility of our common stock. Dividend yield was estimated based on historic and future yield estimates.
The following is a summary of stock performance award activity for the three months ended March 31, 2023 (share amounts reflect awards at target):
 SharesWeighted Average
Grant-Date
Fair Value
Nonvested, January 1, 2023
189,800 $45.95 
Granted59,400 61.97 
Vested(55,000)47.79 
Forfeited— — 
Nonvested, March 31, 2023
194,200 $50.33 
The fair value of vested awards was $5.3 million and $5.1 million during the three months ended March 31, 2023 and 2022, respectively.
13. Earnings Per Share
The numerator used in the calculation of both basic and diluted earnings per common share is net income. The denominator used in the calculation of basic earnings per common share is the weighted average number of common shares outstanding during the period. The denominator used in the calculation of diluted earnings per common share is derived by adjusting basic shares outstanding for the dilutive effect of potential common shares outstanding, which consist of time and performance based stock awards and employee stock purchase plan shares.
The following includes the computation of the denominator for basic and diluted weighted-average shares outstanding for the three months ended March 31, 2023 and 2022:
Three Months Ended March 31,
(in thousands)20232022
Weighted Average Common Shares Outstanding – Basic41,632 41,548 
Effect of Dilutive Securities:
Stock Performance Awards241 219 
Restricted Stock Awards102 102 
Employee Stock Purchase Plan Shares and Other2 2 
Dilutive Effect of Potential Common Shares345 323 
Weighted Average Common Shares Outstanding – Diluted41,977 41,871 
The number of shares excluded from diluted weighted-average common shares outstanding because such shares were anti-dilutive was not material for the three months ended March 31, 2023 and 2022.
14. Derivative Instruments
OTP enters into derivative instruments to manage its exposure to future market energy price variability and reduce volatility in prices for our retail customers. These derivative instruments are not designated as qualifying hedging transactions but provide for an economic hedge against future market energy price variability. The instruments are recorded at fair value on the consolidated balance sheets. In accordance with ratemaking and cost recovery processes, we recognize a regulatory asset or liability to defer losses or gains from derivative activity until settlement of the associated derivative instrument.
As of March 31, 2023, OTP had one outstanding pay-fixed, receive-variable swap agreement with an aggregate notional amount of 8,000 megawatt-hours of electricity, with a settlement date of December 31, 2023. As of March 31, 2023, the fair value of this derivative instrument was $0.3 million, which is included in other current liabilities, on the consolidated balance sheets. As of December 31, 2022, the fair value of these types of derivative contracts was $7.1 million, which is included in other current liabilities. During the three months ended March 31, 2023 and 2022, contracts matured and were settled in an aggregate amount of a $16.0 million loss and a $2.8 million gain, respectively. Gains and losses recognized on the settlement of derivative instruments are recorded in electric purchased power in the consolidated statements of income. Such settlement gains and losses are returned to or recovered from our electric customers through fuel recovery mechanisms in each state.
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15. Fair Value Measurements
The following tables present our assets and liabilities measured at fair value on a recurring basis as of March 31, 2023 and December 31, 2022 classified by the input method used to measure fair value:
(in thousands)Level 1Level 2Level 3
March 31, 2023
Assets:
Investments:
Money Market Funds$2,148 $— $— 
Mutual Funds7,128 — — 
Corporate Debt Securities— 1,450 — 
Government-Backed and Government-Sponsored Enterprises’ Debt Securities— 7,521 — 
Total Assets$9,276 $8,971 $— 
Liabilities:
Derivative Instruments$— $347 $— 
Total Liabilities$— $347 $— 
December 31, 2022
Assets:
Investments:
Money Market Funds$1,560 $— $— 
Mutual Funds5,503 — — 
Corporate Debt Securities— 1,434 — 
Government-Backed and Government-Sponsored Enterprises’ Debt Securities— 7,327 — 
Total Assets$7,063 $8,761 $— 
Liabilities:
Derivative Instruments— 7,130 — 
Total Liabilities$— $7,130 $— 
Level 1 fair value measurements are based on quoted prices (unadjusted) in active markets for identical assets or liabilities that we have the ability to access at the measurement date.
The level 2 fair value measurements for government-backed and government-sponsored enterprises and corporate debt securities are determined based on valuations provided by a third-party pricing service which utilizes industry accepted valuation models and observable market inputs to determine valuation. Some valuations or model inputs used by the pricing service may be based on broker quotes.
The level 2 fair value measurements for derivative instruments are determined by using inputs such as forward electric commodity prices, adjusted for location differences. These inputs are observable in the marketplace throughout the full term of the instrument, can be derived from observable data, or are supported by observable levels at which transactions are executed in the marketplace.
In addition to assets recorded at fair value on a recurring basis, we also hold financial instruments that are not recorded at fair value in the consolidated balance sheets but for which disclosure of the fair value of these financial instruments is provided.
The following reflects the carrying value and estimated fair value of these assets and liabilities as of March 31, 2023 and December 31, 2022:
 March 31, 2023December 31, 2022
(in thousands)Carrying
Amount		Fair ValueCarrying
Amount		Fair Value
Assets:
Cash and Cash Equivalents$104,080 $104,080 $118,996 $118,996 
Total104,080 104,080 118,996 118,996 
Liabilities:
Short-Term Debt60,854 60,854 8,204 8,204 
Long-Term Debt823,882 702,129 823,821 681,615 
Total$884,736 $762,983 $832,025 $689,819 
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The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value:
Cash Equivalents: The carrying amount approximates fair value because of the short-term maturity of those instruments.
Short-Term Debt: The carrying amount approximates fair value because the debt obligations are short-term and the balances outstanding are subject to variable rates of interest which reset frequently, a Level 2 fair value input.
Long-Term Debt: The fair value of long-term debt is estimated based on current market indications for borrowings of similar maturities, a Level 2 fair value input.
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ITEM 2.MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
You should read the following discussion and analysis of our financial condition and results of operations together with our interim financial statements and the related notes appearing under Item 1 of this Quarterly Report on Form 10-Q, and our annual financial statements and the related notes along with the discussion and analysis of our financial condition and results of operations contained in our Annual Report on Form 10-K for the year ended December 31, 2022.
Otter Tail Corporation and its subsidiaries form a diverse group of businesses with operations classified into three segments: Electric, Manufacturing and Plastics. Our Electric segment business is a vertically integrated, regulated utility with generation, transmission and distribution facilities to serve our customers in western Minnesota, eastern North Dakota and northeastern South Dakota. Our Manufacturing segment provides metal fabrication for custom machine parts and metal components and manufactures extruded and thermoformed plastic products. Our Plastics segment manufactures PVC pipe for use in, among other applications, municipal and rural water, wastewater and water reclamation projects.
PVC PIPE SUPPLY AND DEMAND CONDITIONS
Extraordinary supply and demand conditions in the PVC industry beginning in 2021 have led to a significant expansion in operating margins and elevated earnings in our Plastics segment. Periodic disruptions in the supply of resin, the primary material input used in the manufacturing of PVC pipe, coupled with robust demand for resin, led to a significant increase in the cost of resin. Low industry volumes of PVC pipe and robust end market demand for the product led to a rapid and significant increase in sales prices for PVC pipe, significantly outpacing the increase in resin input costs, leading to widening margins within our Plastics segment.
Demand for PVC pipe began to soften in the second half of 2022 and continued through the first quarter of 2023 as distributors and contractors have reduced purchase volumes and inventory levels in response to changing market conditions. Resin prices have declined and stabilized at near historical levels but sales prices for PVC pipe remain elevated, continuing to produce expanded operating margins.
These unique market dynamics impacting our Plastics segment resulted in a significant increase in earnings in 2022 compared to prior periods. We currently expect earnings of our Plastics segment to remain elevated in 2023 compared to pre-2021 levels, but as the industry supply and demand conditions normalize, we expect segment earnings to normalize beginning in 2024.
STEEL PRICING
Volatility in the price of steel, a key material input to our Manufacturing segment, significantly impacted our operating results in 2022. Steel prices, which were highly volatile in 2022, were elevated at the beginning of 2022 but began to steadily decline at the end of the second quarter and returned to near historical levels by the end of the year. Elevated steel prices led to increased sales prices in 2022 for our products at BTD Manufacturing, Inc. (BTD), our metal fabrication business within our Manufacturing segment, as we passed along material cost increases to our customers. Scrap metal prices, which typically follow steel prices, were also elevated from historical levels in the first half of 2022, positively impacting our 2022 financial results. While steel and scrap metal prices began to increase late in the first quarter of 2023, pricing did not reach the level present in the first quarter of 2022, thereby impacting our comparative operating results.
The marketplace dynamics impacting both our Manufacturing and Plastics segments are fluid and subject to change and may impact our operating results prospectively.
RESULTS OF OPERATIONS – QUARTER TO DATE
Provided below is a summary and discussion of our operating results on a consolidated basis followed by a discussion of the operating results of each of our segments: Electric, Manufacturing and Plastics. In addition to the segment results, we provide an overview of our Corporate costs. Our Corporate costs do not constitute a reportable segment but rather consist of unallocated general corporate expenses, such as corporate staff and overhead costs, the results of our captive insurance company and other items excluded from the measurement of segment performance. Corporate costs are added to operating segment totals to reconcile to totals on our consolidated statements of income.
CONSOLIDATED RESULTS    
The following table summarizes consolidated operating results for the three months ended March 31, 2023 and 2022:
(in thousands)20232022$ change% change
Operating Revenues$339,081 $374,904 $(35,823)(9.6)%
Operating Expenses258,411 276,605 (18,194)(6.6)
Operating Income80,670 98,299 (17,629)(17.9)
Interest Expense(9,415)(8,948)(467)5.2 
Nonservice Components of Postretirement Benefits2,412 22 2,390 n/m
Other Income (Expense)2,118 260 1,858 714.6 
Income Before Income Taxes75,785 89,633 (13,848)(15.4)
Income Tax Expense13,304 17,630 (4,326)(24.5)
Net Income$62,481 $72,003 $(9,522)(13.2)%
Operating Revenues decreased $35.8 million primarily due to decreased sales volumes within our Plastics segment and decreased sales prices in our Manufacturing segment. These decreases were partially offset by increased sales prices in our Plastics segment, increased sales volumes in our
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Manufacturing segment and increased operating revenues within our Electric segment. PVC pipe sale volumes decreased as customer demand softened from the same period a year ago amid changing market conditions. Decreased sales prices in our Manufacturing segment were primarily due to decreased steel prices, which are passed through to customers. In our Electric segment, increased fuel recovery revenues, driven by higher purchased power costs and volumes, and increased commercial and industrial sales volumes, contributed to increased operating revenues. See our segment disclosures below for additional discussion of items impacting operating revenues.
Operating Expenses decreased $18.2 million primarily due to lower sales volumes in our Plastics segment and lower material costs in our Manufacturing segment. These decreases were partially offset by an increase in operating expenses in our Electric segment, due to higher purchased power costs and volumes. See our segment disclosures below for additional discussion of items impacting operating expenses.
Interest Expense increased $0.5 million due to increased interest rates on our short-term variable rate debt.
Nonservice Components of Postretirement Benefits increased $2.4 million, having a positive impact on net income, primarily due to a change in actuarial assumptions used to measure our pension benefit and postretirement benefit obligations, including an increase in the discount rate applied and an increase in the expected return on assets assumption.
Other Income increased $1.9 million primarily due to income earned on our short-term cash equivalent investments and gains on our corporate-owned life insurance policies during the first quarter of 2023 compared to investment losses in the same period of the previous year.
Income Tax Expense decreased $4.3 million primarily due to decreased income before income taxes. Our effective tax rate was 17.6% in the first quarter of 2023 and 19.7% in the first quarter of 2022. The decrease in our effective tax rate was driven by an increase in production tax credits from our wind generation assets in the current period. See Note 8 to our consolidated financial statements included in this Quarterly Report on Form 10-Q for additional information regarding factors impacting our effective tax rate in 2023 and 2022.
ELECTRIC SEGMENT RESULTS
The following table summarizes Electric segment operating results for the three months ended March 31, 2023 and 2022:
(in thousands)20232022$ change% change
Retail Revenues$136,453 $113,639 $22,814 20.1 %
Transmission Services Revenues12,107 12,556 (449)(3.6)
Wholesale Revenues1,838 2,463 (625)(25.4)
Other Electric Revenues1,511 1,758 (247)(14.1)
Total Operating Revenues151,909 130,416 21,493 16.5 
Production Fuel11,492 14,853 (3,361)(22.6)
Purchased Power41,825 20,529 21,296 103.7 
Operating and Maintenance Expenses45,549 44,278 1,271 2.9 
Depreciation and Amortization18,326 18,382 (56)(0.3)
Property Taxes4,621 4,432 189 4.3 
Operating Income$30,096 $27,942 $2,154 7.7 %
20232022change% change
Electric kilowatt-hour (kwh) Sales (in thousands)
  
Retail kwh Sales1,635,246 1,515,297 119,949 7.9 %
Wholesale kwh Sales – Company Generation61,854 66,187 (4,333)(6.5)
Heating Degree Days3,732 3,821 (89)(2.3)
The operating results of our Electric segment are impacted by fluctuations in weather conditions and the resulting demand for electricity for heating. The following table shows heating degree days as a percent of normal for the three months ended March 31, 2023 and 2022.
 20232022
Heating Degree Days108.2 %111.8 %
The following table summarizes the estimated effect on diluted earnings per share of the difference in retail kwh sales under actual weather conditions and expected retail kwh sales under normal weather conditions in 2023 and 2022, and between years.
 
2023 vs
Normal
2023 vs
2022
2022 vs
Normal
Effect on Diluted Earnings Per Share$0.03 $(0.01)$0.04 
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Retail Revenues increased $22.8 million primarily due to the following:
•A $16.5 million increase in fuel recovery revenues due to increased purchased power costs and volumes, partially offset by lower production fuel costs due to lower volumes, as described below.
•A $5.4 million increase in retail revenues from increased sales volumes from commercial and industrial customers, including the impact of a new commercial customer load in North Dakota that came online during the first quarter of 2022.
•A $1.4 million increase in renewable resource rider revenue, including recovery of costs related to our Hoot Lake Solar project and the acquisition of the Ashtabula III wind farm.
Retail revenues in the first quarter of 2023 were negatively impacted $0.6 million by unfavorable weather.
Production Fuel costs decreased $3.4 million primarily as a result of an outage at Big Stone Plant in the first quarter of 2023, which resulted in lower volumes of coal consumption.
Purchased Power costs to serve retail customers increased $21.3 million due to a 42% increase in the price of purchased power per kwh, primarily due to increased market energy costs, and a 43% increase in the volume of purchased power due to the outage at Big Stone Plant and increased customer demand.
Operating and Maintenance Expenses increased $1.3 million primarily due to an increase in maintenance activities, including the outage at Big Stone Plant and incremental costs associated with the Ashtabula III wind farm facility.
MANUFACTURING SEGMENT RESULTS
The following table summarizes Manufacturing segment operating results for the three months ended March 31, 2023 and 2022:
(in thousands)20232022$ change% change
Operating Revenues$106,782 $104,957 $1,825 1.7 %
Cost of Products Sold (excluding depreciation)82,227 86,161 (3,934)(4.6)
Other Operating Expenses10,578 8,847 1,731 19.6 
Depreciation and Amortization4,468 4,014 454 11.3 
Operating Income$9,509 $5,935 $3,574 60.2 %
Operating Revenues increased $1.8 million due to increased sales volumes at BTD Manufacturing, our contract metal fabricator, as strong customer and end market demand in the Energy, Agriculture, Power Generation, and Construction markets contributed to a 19% increase in sales volumes. Sales price increases also contributed to the growth in operating revenues. These were implemented in response to labor and non-steel material cost inflation. Increased sales volumes and price increases were largely offset by a 21% decrease in material costs, which are passed through to customers, as steel prices have declined from the same time a year ago. Scrap revenues were lower in the first quarter due to lower scrap metal prices. Operating revenues at T.O. Plastics, our plastics thermoforming manufacturer, also increased compared to last year, primarily due to sales price increases.
Cost of Products Sold decreased $3.9 million primarily due to decreased material costs, as described above, largely offset by increased sales volumes, as well as increased labor and other production costs.
Other Operating Expenses increased $1.7 million due to variable costs associated with increased business activity and financial performance during the period.
PLASTICS SEGMENT RESULTS
The following table summarizes Plastics segment operating results for the three months ended March 31, 2023 and 2022:
(in thousands)20232022$ change% change
Operating Revenues$80,390 $139,531 $(59,141)(42.4)%
Cost of Products Sold (excluding depreciation)30,142 65,598 (35,456)(54.1)
Other Operating Expenses3,529 3,964 (435)(11.0)
Depreciation and Amortization1,036 1,107 (71)(6.4)
Operating Income$45,683 $68,862 $(23,179)(33.7)%
Operating Revenues decreased $59.1 million due to a 46% decrease in sales volumes, partially offset by a 7% increase in the price per pound of PVC pipe sold compared to the same period last year. Sales volume decreases were attributable to distributor customer inventory management as distributors continue to closely manage their inventory levels amid changing market conditions, overall economic uncertainty, including uncertainty in the housing market, and the impact of unfavorable weather conditions during the first quarter of 2023. Sales prices declined from the fourth quarter of 2022 but remained elevated compared to pre-2021 levels.
Cost of Products Sold decreased $35.5 million primarily due to decreased sales volumes, as described above. PVC resin and other input material costs decreased 20% compared to the same period in the previous year as the unique supply and demand conditions which caused significant increases in resin costs have subsided and resin costs have stabilized.
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CORPORATE COSTS
The following table summarizes Corporate operating results for the three months ended March 31, 2023 and 2022:
(in thousands)20232022$ change% change
Other Operating Expenses$4,592 $4,395 $197 4.5 %
Depreciation and Amortization26 45 (19)(42.2)
Operating Loss$4,618 $4,440 $178 4.0 %
REGULATORY MATTERS
The following provides a summary of rate rider filings and other regulatory filings that have or are expected to have a material impact on our operating results, financial position or cash flows.
RATE RIDERS
The following table includes a summary of pending and recently concluded rate rider proceedings:
RecoveryFilingAmountEffective
MechanismJurisdictionStatusDate(in millions)DateDescription
RRR - 2022MNRequested11/01/22$17.5 07/01/23Recovery of Hoot Lake Solar costs, Ashtabula III costs, and true up for PTCs from Merricourt.
CIP - 2022MNApproved04/01/2210.8 10/01/22Recovery of energy conservation improvement costs as well as a demand side management financial incentive.
CIP - 2023MNRequested04/03/239.7 10/01/23Recovery of energy conservation improvement costs as well as a demand side management financial incentive.
TCR - 2021MNApproved11/23/217.2 08/01/22Recovery of transmission project costs.
RRR - 2021MNApproved12/06/217.0 08/01/22Recovery of Hoot Lake Solar and Ashtabula III costs.
EITE - 2023MNRequested04/14/232.2 01/01/24Biennial update to Energy-Intensive, Trade-Exposed rider.
TCR - 2023MNRequested04/07/231.7 01/01/24Recovery of transmission project costs.
EUIC - 2023MNRequested03/20/231.3 07/01/23Recovery of advanced metering infrastructure, outage management and demand response system projects.
RRR - 2023NDApproved04/27/2312.2 05/01/23Recovery of Ashtabula III and other costs.
RRR - 2022NDApproved01/05/227.8 04/01/22Recovery of Merricourt costs, Ashtabula III costs, and deferred taxes and production tax credits.
TCR - 2022NDApproved09/15/227.5 01/01/23Recovery of transmission project costs.
TCR - 2021NDApproved09/15/216.1 01/01/22Recovery of transmission project costs.
GCR - 2022NDApproved03/01/223.3 07/01/22Annual update to generation cost recovery rider.
AMDT - 2022NDApproved07/08/223.1 01/01/23Recovery of advanced metering infrastructure, outage management system and demand response projects.
GCR - 2023NDRequested03/03/232.2 07/01/23Recovery of Astoria Station, net of anticipated savings associated with the retirement of Hoot Lake Plant.
PIR - 2022SDApproved06/01/223.0 09/01/22Recovery of Ashtabula III, Merricourt, Astoria Station, Advanced Grid Infrastructure project costs, and impact of load growth credits.
TCR - 2022SDApproved11/01/223.0 03/01/23Recovery of transmission project costs.
TCR - 2021SDApproved10/29/212.2 03/01/22Recovery of transmission project costs.
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Renewable Resource Rider (RRR) and Energy Adjustment Rider (EAR): In December 2022, OTP filed an update to its North Dakota RRR. The update included, among other items, a request to modify load allocation factors in North Dakota given the large new load added in the state in 2022. In January 2023, OTP filed an update to its North Dakota EAR proposing to refund MISO planning resource auction revenues to North Dakota customers if the North Dakota Public Service Commission (NDPSC) approves the load allocation factor modification as filed in the RRR docket. In April 2023, the NDPSC denied the request to modify load allocation factors and approved the modification to the EAR allowing for planning resource auction revenues to be refunded to customers. OTP will begin incorporating the planning resource auction revenue refunds in May of 2023.
MISO PLANNING RESOURCE AUCTION
OTP offered 88-megawatts of excess capacity into the annual MISO planning resource auction for the period June, 2022 through May, 2023. As a result of a capacity shortage in the MISO region, capacity prices cleared the auction at maximum pricing. As a result, the 88-megawatts of auctioned capacity will generate approximately $9.3 million of net capacity auction revenues over the twelve-month period ending in May, 2023. The Minnesota and North Dakota allocated portion of net capacity auction revenues will be returned to customers through the FCA mechanism and EAR, respectively. The Minnesota and North Dakota commission have also each ruled that in future periods any capacity auction revenues or costs are to be passed on to customers.
INTEGRATED RESOURCE PLAN
On March 31, 2023, OTP submitted a supplemental resource plan filing to the MPUC, the NDPSC, and the South Dakota Public Utilities Commission. The supplemental filing updates OTP’s original 2022 Integrated Resource Plan (2022 IRP), which was filed on September 1, 2021. In the supplemental filing, OTP outlined its updated plan for meeting customers’ anticipated capacity and energy needs while maintaining system reliability and low electric service rates, in light of several changes that have occurred since the original filing, including significant winter and spring reserve planning margins adopted by MISO, tax credits made available for renewable energy projects under the Inflation Reduction Act, the enactment of the Clean Energy Bill in Minnesota, and recent volatility in energy and capacity markets.
The major requests in OTP's supplemental filing include:
•the addition of on-site liquefied natural gas fuel storage at our Astoria Station natural gas plant in 2026;
•the addition of approximately 200 megawatts of solar generation in 2027-2028;
•undertaking the initial steps necessary to add approximately 200 megawatts of wind generation in 2029; and
•a withdrawal from our 35 percent ownership interest in Coyote Station, a jointly-owned coal-fired generation plant, in the event we are required to make a major, non-routine capital investment in the plant.
Consistent with the original 2022 IRP, the supplemental filing proposes to, subject to regulatory approval, create a regulatory asset to recover costs related to any future withdrawal from Coyote Station. Should such a withdrawal occur, we anticipate the regulatory asset would include the net book value of the plant on the withdrawal date, anticipated decommissioning costs, and any costs incurred if the existing lignite sales agreement, under which Coyote Station acquires all of its lignite coal, must be terminated. As part of an economic analysis included in the filing, OTP developed an estimate of the reasonably foreseeable costs of withdrawing from Coyote Station, which was determined to be $68.5 million, assuming a withdrawal at the end of 2028. These costs may differ from actual results due to the uncertainty and timing of future events which could result in a withdrawal from Coyote Station.
LIQUIDITY
LIQUIDITY OVERVIEW
We believe our financial condition is strong and our cash and cash equivalents, other liquid assets, operating cash flows, existing lines of credit, access to capital markets and borrowing ability, because of investment-grade credit ratings, when taken together provide us ample liquidity to conduct our business operations, fund our short-term and long-term capital expenditure plans and satisfy our obligations as they become due. Our liquidity, including our operating cash flows and access to capital markets, could be impacted by macroeconomic factors outside of our control, including higher interest rates and debt capital costs and diminished credit availability. In addition, our liquidity could be impacted by non-compliance with certain financial covenants under our various debt instruments. As of March 31, 2023, we were in compliance with all financial covenants (see the Financial Covenants section under Capital Resources below).
The following table presents the status of our lines of credit as of March 31, 2023 and December 31, 2022:
20232022
(in thousands)Borrowing LimitAmount OutstandingLetters
of Credit		Amount AvailableAmount Available
OTC Credit Agreement$170,000 $— $— $170,000 $170,000 
OTP Credit Agreement170,000 60,854 9,573 99,573 152,223 
Total$340,000 $60,854 $9,573 $269,573 $322,223 
We have an internal risk tolerance metric to maintain a minimum of $50 million of liquidity under the OTC Credit Agreement. Should additional liquidity be needed, this agreement includes an accordion feature allowing us to increase the amount available to $290 million, subject to certain terms and conditions. The OTP Credit Agreement also includes an accordion feature allowing OTP to increase that facility to $250 million, subject to certain terms and conditions.
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CASH FLOWS
The following is a discussion of our cash flows for the three months ended March 31, 2023 and 2022:
(in thousands)20232022
Net Cash Provided by Operating Activities$55,553 $45,416 
Net Cash Provided by Operating Activities increased $10.1 million for the three months ended March 31, 2023 compared to the three months ended March 31, 2022, primarily due to the absence of a pension plan contribution in 2023 due to the plan's funded status, whereas a $20.0 million discretionary contribution was made in February 2022, as well as a lower level of working capital needs compared to the same period in the previous year.
(in thousands)20232022
Net Cash Used in Investing Activities$100,379 $31,449 
Net Cash Used in Investing Activities increased $68.9 million for the three months ended March 31, 2023 compared to the three months ended March 31, 2022. The increase in cash used in investing activities was primarily due to a higher amount of Electric segment capital investment compared to last year, including the purchase of the Ashtabula III wind farm in January 2023 for $50.6 million.
(in thousands)20232022
Net Cash Provided by (Used in) Financing Activities$29,910 $(14,133)
Net Cash Provided by (Used in) Financing Activities increased $44.0 million for the three months ended March 31, 2023 compared to the three months ended March 31, 2022. Financing activities for the three months ended March 31, 2023 included net proceeds from short-term borrowings of $52.7 million which were primarily used to fund the acquisition of Ashtabula III, and dividend payments of $18.3 million. Financing activities for the three months ended March 31, 2022 included net proceeds from short-term borrowings of $6.6 million and dividend payments of $17.2 million.
CAPITAL REQUIREMENTS
CAPITAL EXPENDITURES
We have a capital expenditure program for expanding, upgrading and improving our plants and operating equipment. Typical uses of cash for capital expenditures are investments in electric generation facilities and environmental upgrades, transmission and distribution lines, manufacturing facilities and upgrades, equipment used in the manufacturing process, and computer hardware and information systems. Our capital expenditure program is subject to review and regulatory approval and is revised in light of changes in demands for energy, technology, environmental laws, tax laws, regulatory changes, business expansion opportunities, the costs of labor, materials and equipment, and our financial condition.
We have increased our Electric segment five-year capital expenditure plan by approximately $45 million to incorporate the proposed capital investments through 2027 that are included in OTP's supplemental IRP filed on March 31, 2023.
The following provides a summary of actual capital expenditures for the year ended December 31, 2022, anticipated annual capital expenditures for the current year ending December 31, 2023, and the subsequent four years, along with electric utility average rate base and annual rate base growth:
(in millions)2022
2023(1)
2024202520262027Total
2023 - 2027
Electric Segment:
Renewables and Natural Gas Generation$88 $119 $88 $85 $49 $429 
Technology and Infrastructure33 30 6 5 1 75 
Distribution Plant Replacements33 37 38 38 43 189 
Transmission (includes replacements)34 36 46 87 78 281 
Other26 25 30 24 23 128 
Total Electric Segment$148 $214 $247 $208 $239 $194 $1,102 
Manufacturing and Plastics Segments23 48 53 29 25 24 179 
Total Capital Expenditures$171 $262 $300 $237 $264 $218 $1,281 
Total Electric Utility Average Rate Base$1,624 $1,748 $1,851 $1,990 $2,111 $2,230 
Annual Rate Base Growth3.1 %7.6 %5.9 %7.5 %6.1 %5.6 %
(1) Includes actual results for the three months ended March 31, 2023, and anticipated capital expenditures for the remaining nine months of 2023.
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CONTRACTUAL OBLIGATIONS
Our contractual obligations primarily include principal and interest payments due under our outstanding debt obligations, commitments to acquire coal, energy and capacity commitments, payments to meet our postretirement benefit obligations, and payment obligations under land easements and leasing arrangements.
Our contractual obligations as of December 31, 2022 are included in Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations, of our Annual Report on Form 10-K for the year ended December 31, 2022. Except for the obligations arising from new land easements assumed in connection with the purchase of Ashtabula III, there were no material changes in our contractual obligations outside of the ordinary course of our business during the three months ended March 31, 2023.
In connection with the purchase of the Ashtabula III wind farm in January 2023, we assumed 51 land easements not classified as leases, which require annual payments. The remaining payments to be made under the easements total $4.2 million and the remaining terms of the agreements extend into 2034.
COMMON STOCK DIVIDENDS
We paid dividends to our common stockholders totaling $18.3 million, or $0.4375 per share, in the first three months of 2023. The determination of the amount of future cash dividends to be paid will depend on, among other things, our financial condition, our actual or expected level of earnings and cash flows from operations, the level of our capital expenditures and our future business prospects. As a result of certain statutory limitations or regulatory or financing agreements, the amount of dividends we are allowed to pay could be restricted. See Note 10 to our consolidated financial statements included in this Quarterly Report on Form 10-Q for additional information. The decision to declare dividends is reviewed quarterly by our Board of Directors.
CAPITAL RESOURCES
Financial flexibility is provided by operating cash flows, unused lines of credit and access to capital markets and is aided by strong financial coverages and investment grade credit ratings. Debt financing will be required in the five-year period from 2023 through 2028 to refinance maturing debt and to finance our capital investments. Our financing plans are subject to change and are impacted by our planned level of capital investments, and decisions to reduce borrowings under our lines of credit, to refund or retire early any of our outstanding debt, to complete acquisitions, or to use capital for other corporate purposes.
REGISTRATION STATEMENTS
On May 3, 2021, we filed a shelf registration statement with the SEC under which we may offer for sale, from time to time, either separately or together in any combination, equity, debt or other securities described in the shelf registration statement. No new debt or equity has been issued pursuant to the registration statement. The registration statement expires in May 2024.
On May 3, 2021, we filed a second registration statement with the SEC for the issuance of up to 1,500,000 common shares under an Automatic Dividend Reinvestment and Share Purchase Plan, which provides shareholders, retail customers of OTP and other interested investors methods of purchasing our common shares by reinvesting their dividends or making optional cash investments. Shares purchased under the plan may be newly issued common shares or common shares purchased on the open market. As of March 31, 2023, there were 1,220,100 shares available for purchase or issuance under the plan. The registration statement expires in May 2024.
SHORT-TERM DEBT
OTC and OTP are each party to a credit agreement (the OTC Credit Agreement and the OTP Credit Agreement, respectively) which each provide for unsecured revolving lines of credit. The following is a summary of key provisions and borrowing information as of, and for the three months ended, March 31, 2023:
(in thousands, except interest rates)OTC Credit AgreementOTP Credit Agreement
Borrowing Limit$170,000 $170,000 
Borrowing Limit if Accordion Exercised1
290,000 250,000 
Amount Restricted Due to Outstanding Letters of Credit as of March 31, 2023
— 9,573 
Amount Outstanding as of March 31, 2023
— 60,854 
Average Amount Outstanding During the Three Months Ended March 31, 2023
— 51,226 
Maximum Amount Outstanding During the Three Months Ended March 31, 2023
— 61,006 
Interest Rate as of March 31, 2023
6.30 %6.01 %
Maturity DateOctober 29, 2027October 29, 2027
1Each facility includes an accordion featuring allowing the borrower to increase the borrowing limit if certain terms and conditions are met.
LONG-TERM DEBT
As of March 31, 2023, we had $827.0 million of principal outstanding under long-term debt arrangements. These instruments generally provide for unsecured borrowings at fixed rates of interest with maturities ranging from 2026 to 2052. Note 6 to our consolidated financial statements included in this Quarterly Report on Form 10-Q includes additional information regarding these short-term and long-term debt instruments.
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Financial Covenants
Certain of our short- and long-term debt agreements require OTC and OTP to maintain certain financial covenants. As of March 31, 2023, we were in compliance with these financial covenants as further described below:
OTC, under its financial covenants, may not permit its ratio of interest-bearing debt to total capitalization to exceed 0.60 to 1.00, may not permit its interest and dividend coverage ratio to be less than 1.50 to 1.00, and may not permit its priority indebtedness to exceed 10 percent of its total capitalization. As of March 31, 2023, OTC's interest-bearing debt to total capitalization was 0.412 to 1.00, OTC's interest and dividend coverage ratio was 10.62 to 1.00, and OTC had no priority indebtedness outstanding.
OTP, under its financial covenants, may not permit its ratio of interest-bearing debt to total capitalization to exceed 0.60 to 1.00, may not permit its interest and dividend coverage ratio to be less than 1.50 to 1.00, and may not permit its priority indebtedness to exceed 20 percent of its total capitalization. As of March 31, 2023, OTP's interest-bearing debt to total capitalization was 0.467 to 1.00, OTP's interest and dividend coverage ratio was 3.73 to 1.00, and OTP had no priority indebtedness outstanding.
CRITICAL ACCOUNTING POLICIES INVOLVING SIGNIFICANT ESTIMATES
The discussion and analysis of our results of operations are based on financial statements prepared in accordance with generally accepted accounting principles in the United States of America. Certain of our accounting policies require management to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities in the preparation of our consolidated financial statements. We have disclosed in our Annual Report on Form 10-K for the year ended December 31, 2022 the critical accounting policies that affect our most significant estimates and assumptions used in preparing our consolidated financial statements. There have been no material changes to our critical accounting policies and estimates from those disclosed in the most recent Annual Report on Form 10-K.
ITEM 3.QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
There have been no material changes in our market risk from those disclosed in Item 7A, Quantitative and Qualitative Disclosures About Market Risk, in our Annual Report on Form 10-K for the year ended December 31, 2022.
ITEM 4.CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures. Under the supervision and with the participation of the Company’s management, including the Chief Executive Officer and the Chief Financial Officer, we evaluated the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934 (the Exchange Act)) as of March 31, 2023, the end of the period covered by this report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of March 31, 2023.
Changes in Internal Control over Financial Reporting. There were no changes in our internal control over financial reporting (as defined in Rules 13a-15(f) under the Exchange Act) during the quarter ended March 31, 2023 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
We are the subject of various legal and regulatory proceedings in the ordinary course of our business. Such matters are subject to many uncertainties and to outcomes that are not predictable with assurance. We record a liability in our consolidated financial statements for costs related to claims, including future legal costs, settlements and judgments, where we have assessed that a loss is probable, and an amount can be reasonably estimated. Material proceedings are described under Note 9, Commitments and Contingencies, to the consolidated financial statements, and in Management's Discussion and Analysis of Financial Condition and Results of Operations, Regulatory Matters.
ITEM 1A.RISK FACTORS
There have been no material changes from the risk factors disclosed in Item 1A, Risk Factors, of our Annual Report on Form 10-K for the year ended December 31, 2022.
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ITEM 6.EXHIBITS
The following Exhibits are filed as part of, or incorporated by reference into, this report.
 No.Description
31.1
31.2
32.1
32.2
101.SCH—Inline XBRL Taxonomy Extension Schema Document
101.CAL—Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.LAB—Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE—Inline XBRL Taxonomy Extension Presentation Linkbase Document
101.DEF—Inline XBRL Taxonomy Extension Definition 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 Section 13 or 15(d) 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.
 OTTER TAIL CORPORATION
By:/s/ Kevin G. Moug
  Kevin G. Moug
Chief Financial Officer and Senior Vice President
(duly authorized officer and principal financial officer)
 Dated: May 3, 2023
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